Global Voice of Gas - Volume 1, Issue 5 by IGU

Global Voice of Gas BY T H E I N T E R N AT I O N A L G A S U N I O N ISSUE 05 | VOL 01

How Gas will Fuel the Path from Glasgow A sustainable flame: the role of gas in net zero

Clean technologies that will make gas and gas use emission-free

The US Gulf Coast is poised for rapid methane and CCS development

Providing natural gas Investing in natural gas to reduce the carbon footprint of the global energy mix

Total Energies

Contents FEATURES

18 22 26

A sustainable flame: the role of gas in net zero Clean technologies that will make gas and gas use emission-free The road to net-zero: GECF’s perspective

40 45

Gas in their sights: the fuel’s place in net-zero strategies

The US Gulf Coast is poised for rapid methane and CCS development

49 52

Making CCUS pay: The US perspective Complementary colours: developing blue and green hydrogen trade Methane pyrolysis: a potential gamechanger? The decarbonisation prize of biomethane de-mystified

Greening our gas grids: Should we leave for tomorrow what we can do today?

60 63 66

Africa disproportionately hit by investors’ reluctance to back oil, gas Nigeria kickstarts decade of gas with new petroleum bill Pakistan’s upstream declines will drive LNG demand

EU Fit for 55: From an existential threat to an opportunity?

From the President.......5

Regional Update

Editor’s Note.................. 6

The Middle East & Africa ................................ 11

South & Southeast Asia.................................... 13

Events ............................. 8

Russia, Black Sea and the Caspian Area...... 12

North East Asia & Australasia......................... 15

The opinions and views expressed by the authors in this magazine are not necessarily those of IGU, its members or the publisher. While every care has been taken in the preparation of this magazine, they are not responsible for the authors’ opinions or for any inaccuracies in the articles.

G L O B A L VO I C E O F G A S

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Messages From the President

change and the contribution of 21st

including hydrogen, biomethane, and

century society and its way of life

abated natural gas tomorrow are the

to those.

catalyst for and foundation of a more sustainable energy future.

We believe that natural gas today

renewables has already removed or

decarbonised and renewable gases

reduced more polluting fuels from

– are a major solution to all of these

multiple markets, cleaned the air in

challenges. One could argue that

cities, and cut CO2 emissions. Natural

importance is reflected by strong

gas-powered electricity generation

demand today, which is projected

produces less than half of the GHG

to continue. There is, of course, an

emissions than that of coal and up to

ongoing debate about the energy

a third less than oil and is a perfect

transition but at the same time, the

combination with currently intermittent

world understands the unique value

renewable installed capacity.

of natural gas, continuing to invest, Dear reader,

The combination of gas and

– and in the future a portfolio of

This is a trend which will continue

transport and utilise the blue fuel.

and develop as technologies in both

This edition however is focused

gas and renewables are enhanced –

Welcome to another issue of the Global

on how our industry can help support

for instance wide scale adoption of

Voice of Gas, the digital magazine of the

global society in managing just one

CC(U)S to ensure that there is as little

International Gas Union.

of these dynamics. This edition is

unabated gas in the system as possible,

dedicated to one of the most important

and existing natural gas infrastructure

driven isolation, the gas value chain

shared challenges of our time. Global

that can be used for a more sustainable

has many reasons to be positive. This is

warming and climate change are real

future – for instance with blending of

because, as we near the end of 2021, gas

– and we cannot ignore the major

molecules for a lower carbon solution, or

in its broadest sense – whether that is

contributing role of the energy value

even fully switching to hydrogen.

natural gas or a portfolio of decarbonised

chain. It is not the only cause, but

and renewable gases – has never been as

we must recognise that we have an

new gas technologies that the great

important to global society.

obligation to publicly be part of the

challenge of our time will be managed –

solution – or offer a range of solutions.

and managed in a just manner.

As we all emerge from our COVID

We are all in the midst of multiple challenging interconnected global

I want to be very clear in stating

It is through the use of available and

The IGU is committed to being

dynamics, all of which require timely action

that the IGU fully supports the Paris

an important contributor to climate,

and significant resources to be resolved:

Agreement, the urgent need for action to

energy transition, and sustainable future

reduce GHG emissions, and the need for

discussions, both as a forum for inter-

significant decarbonisation of the global

industry engagement and as the Global

energy system to meet these goals.

Voice of Gas, engaging with a range of

1. Energy access – every human on the planet should have reliable, secure, affordable energy access 2. Socio economic development – all

We recognise the challenge of

global partners and stakeholders. I hope

global warming and can demonstrate

you find this edition of Global Voice of

societies must have the right to

that we are an inherent part of the

Gas informative and engaging.

develop their economies to enhance

solution, based on proven technology

the life of their people

and viable return on investments. We

3. Sustainability and the environment

believe that natural gas today and

—Professor Joe M Kang

– real dangers posed by climate

a portfolio of decarbonised gases,

President, International Gas Union

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Editors’ Note

elcome to the fifth issue of Global Voice

In further driving down emissions, great progress

of Gas (GVG), an International Gas Union

can be made by deployment of clean technologies,

magazine produced in collaboration

such as renewable gases, low-and-zero-carbon

with Natural Gas World – setting a new standard

hydrogen, and carbon capture, utilisation and

in communication for the gas industry and its

storage. Existing gas infrastructure will be critical

stakeholders worldwide.

for that, as it is a key conduit for scaling renewable

Ahead of the crucial UN Climate Change

gases and hydrogen sufficiently to decarbonise entire

Conference (COP26) in November, the IGU has

energy systems. The costs for these technologies are

dedicated this issue to the environmental and

coming down, but prudent policy support, access

economic value of natural gas, making the case

to financing, and a great entrepreneurial spirit from

for its founding role in the energy transition, in

both the incumbent and new industry players are

sustainable development, and in improving lives and

needed for these technologies to reach the required

livelihoods around the world.

deployment levels.

That case grows stronger with the ongoing

This issue shines a spotlight on several key

development of low-carbon gas technologies,

developments in low-carbon gas technologies.

which help to position gas as a vital second pillar in

For instance, we examine the potential for CCUS

decarbonisation, alongside renewables – the pathway

deployment in the US Gulf Coast, as well as the

envisioned by IHS Markit in their recent Sustainable

incentives required to scale it up into a multi-trillion-

Flame report.

dollar industry. We also discuss the state of play

Gas is already driving emissions reductions

in methane pyrolysis technology, used to produce

across the world, most evidently in Asia, by replacing

low-emission hydrogen and solid carbon, as well as

more polluting fuels such as coal – but also in Europe

how the global market for various hydrogen types

and the Americas. An expansion in gas supply and

will take shape.

the infrastructure to import and distribute it has also

The IGU is proud to include contributions from

been instrumental in increasing access to modern,

the IHS Markit’s Michael Stoppard on the key role

reliable and sustainable energy in developing nations,

of gas in the energy transition as the second pillar

helping to eliminate energy poverty, clean up the air

of decarbonisation, the Gulf Coast Carbon Center

people breathe and bringing back blue skies to where

researchers, the European Biogas Association, and

they were black before.

the Gas Exporting Countries Forum.

It is therefore critical to avoid a one-size-

The issue also explores several key recent

fits-all approach to addressing climate change,

developments affecting the global gas market,

safeguarding reliable energy supply. Different

including: how the energy transition strategies

nations may pursue different transition paths toward

of international oil companies have affected

the Paris Agreement, depending on their starting

investment in Africa; Nigeria’s passing of a long-

positions, available resources and the needs of their

awaited petroleum bill; shortages in energy supply in

populace. And in many countries, gas will serve

Pakistan; and the European Commission’s unveiling

as an indispensable source of energy enabling the

of its Fit for 55 climate package.

increasing use of renewable energy. In developed countries, the role of gas in keeping energy affordable and driving economic growth must

— Paddy Blewer Director of Public Affairs, IGU

also be recognised. Investment in new gas supply

must continue, to prevent a spike in energy costs and

— Joseph Murphy

a resurgence in dirtier energy sources, such as coal.

Editor of Global Voice of Gas, Natural Gas World

G L O B A L VO I C E O F G A S

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Events

The Pathway to Serendipity As we look forward to gathering again in person, starting with the World Gas Conference in May 2022, I am reminded of one of my favourite words occurrence and development of events by chance in a happy or beneficial

RODNEY COX Director of Events, International Gas Union

way. Whether it’s the unexpected introduction, the industry gossip that helps you “join the dots” on how things really work, or the depth of knowledge gained through several days of focused involvement, you have to be in the room to create your own serendipity. Momentum is gathering for the IGU’s Flagship Events portfolio and all our host National Organising Committees are taking the opportunity to travel and engage with the industry around the world. Our teams will be in St Petersburg, Abu Dhabi, and Houston soon so if you would like to meet up with them contact me on rodney.cox@igu.org

G L O B A L VO I C E O F G A S

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PHOTO: ISTOCK.COM/G-STOCKSTUDIO

that describes the benefits of meeting face to face – “serendipity”: the

EVENTS

WGC2022

LNG2023 Ahead of the launch of our Call for Papers you can take the survey at ClubLNG to add value in shaping the LNG2023

While the WGC2022 Call for Papers has already received hundreds of insightful submissions from over 25 countries across the 60+ topic sessions, there is still the opportunity to make your contribution and submit an abstract. We invite you to submit your success stories, engaging case studies, projects, strategies, technical research, or

Conference Programme. Plus, you will receive free access to the 1000+ papers presented at every LNG Event Series since LNG 1 in 1968. For a comprehensive video tour of our venue, Expo Forum in St Petersburg, go to lng2023.com/venue-video-tour For exhibitor and sponsoring inquiries please contact the team at exhibition@lng2023.com.

expertise you want to share with the gas and energy industry. Don’t miss your opportunity to present your commercial and technical knowledge to industry professionals from across the entire gas value chain and inspire the global

IGRC2024

audience. Submit your abstract for the Call for Papers by January 28, 2022 and speak

September 29 saw

at the world’s largest face-to-face industry

the official launch by

conference in Daegu, Korea on May 23-27,

the Canadian Gas

2022. Details at wgc2022.org or contact the

Association of IGRC2024

conference team at papers@wgc2022.org

during the Canadian Gas

There is also exciting news on the

Dialogues Conference – a

exhibition and sponsorship as WGC2022

major Canadian industry

continues to add key industry leaders as

event. Despite COVID restrictions over 100 participants came to

supporters of the event. Just confirmed

Calgary for the event. This included accredited media from leading

in the last month are Venture Global,

Canadian papers including The National Post and The Calgary

TotalEnergies, Woodside & SK among many

Herald, and trade paper coverage from the BoE Report, Natural Gas

others. For a closer look at the opportunities

World and Natural Gas Intelligence. Plus, the IGRC2024 team had the

available, the organising team have provided

opportunity to brief various Government of Alberta officials, including

a video briefing which includes a tour of

Dale Nally, Alberta’s Minister of Natural Gas and Electricity, about

the conference facility, an outline of the

our programme of activities to promote gas innovation and to deliver

conference programme and details of

a successful IGRC2024.

the exhibition pavilions including an area

Later this year will see the launch of the IGRC2024 website which

dedicated to hydrogen technologies. Check

will include our plans on developing a series of activities to profile

it out at wgc2022.org/exhibitor-briefing or

innovation and technology leadership across the entire natural gas

contact the exhibition and sponsorship team

value chain. Contact the IGRC2024 Executive Director, Julie Gaudreau,

now: exhibition@wgc2022.org.

for more details at JGaudreau@cga.ca

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Regional Update The Middle East & Africa KHALED ABUBAKR Chairman, Egyptian Gas Association. Executive Chairman, TAQA Arabia and IGU Regional Coordinator

Natural gas is one of the pillars of global energy. Where it replaces more polluting fuels, it improves air quality and limits emissions of CO2. Since 2010, coal-to-gas switching has saved around 500mn metric tons of CO2 – an effect equivalent to putting an extra 200mn EVs running on zerocarbon electricity on the road over the same period. Major power crises are developing around the world with

The area of coastline shared between Mauritania and

capacity shortages, forced industry shutdowns and the

Senegal is rich in hydrocarbons, after lucrative gas basins

restarting of coal-fired generation in some parts of the world.

were discovered six years ago on the edge of the world’s

With the help of its huge state-of-the-art gas-fired power

largest cold-water coral reef, a discovery which set in motion

stations, though, Egypt has been able to emerge from the

the $4.8bn Greater Tortue Ahmeyim (GTA) project led by

crisis and has an abundance of electricity. It is now a major

UK oil and gas giant BP, in partnership with US deepwater

energy and electricity hub with connections to neighbouring

exploration company Kosmos Energy and other firms.

countries and a great potential for electricity exports. The Iraqi Gas Master Plan will rapidly increase development South Africa, which is reliant on coal and is the world’s 12th-

of Iraq’s associated gas resources, most of which are being

biggest source of greenhouse gases, is turning to gas-fired

burned off. The Basra gas gathering project costing around

generation as well. It plans to use natural gas to produce at

$17.2bn forms a major part of this project and will help

least a quarter of almost 12,000 MW of additional power it

provide gas to the domestic power industry as well as for

envisages by 2030. These plants will generate less than half

export as LNG via a floating liquefaction facility off Basra.

the greenhouse gases that coal-based capacity does.

The project is looking to produce 2bn ft3/day of gas flared primarily from three oilfields in the south of the country:

Leading Sub-Saharan Africa building solutions company,

Rumaila, Zubair and West Qurna Phase 1. The three fields

Lafarge Africa, has launched a new fleet of 52 LNG-fuelled

currently produce 1.05bn ft3/d of gas, but only 450mn ft3/d is

trucks. In partnership with Ecologique, the new trucks will

utilised while the rest is flared.

(30% less) and coal (45% less). The focus on the increased

The Hail and Ghasha sour gas fields, located offshore Abu

utilisation of LNG has seen CO2 emissions being reduced

Dhabi, are being developed by ADNOC with the intention

globally and data from the Energy Information Administration

of producing up to 1.5bn ft3/d of sour gas plus additional

has shown that, since 2006, increased use of natural gas has

condensate. The project is intended to increase the UAE’s

driven CO2 savings.

domestic gas production by 18%.

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PHOTO: LAFARGE

contribute far less CO2 to the environment than fuel oil

R E G I O N A L U P D AT E

Russia, Black Sea and the Caspian Area MARCEL KRAMER President, Energy Delta Institute, IGU Regional Coordinator

Strong demand for Russian gas in Europe Demand for Russian gas has been strong in Europe this year due to a colder winter and a recovery in energy consumption as economic activity has increased. Gazprom’s pipeline exports to Europe and Turkey totalled 131bn m3 in the first eight months of the year. This represents an almost 20% increase over the same period in 2020. Domestic supply rose by some 11% in the same period. Deliveries to China through the Power of Siberia pipeline infrastructure repeatedly set new records this year and exceeded contractually planned levels by more than 5%. Yamal LNG exports also grew again, by some 5% in the first half of the year, according to Novatek. A fourth LNG train was reportedly put into full operation around the middle of the year.

Pipeline infrastructure development The Nord Stream 2 pipeline system will be able to deliver gas to European customers via the German landfall this PHOTO: ISTOCK.COM/LEONID IKAN

year, according to Gazprom‘s senior management. The Nord Stream company applied for a ‘precautionary certification’ from the Federal Network Agency (German regulator) as an Independent Transmission Operator (ITO). Trans Adriatic pipeline (TAP), which links gas from Azerbaijan to Southern Europe via Turkey, launched its Market Test in July. This process aims at gathering additional interest in shipping gas through TAP. Depending on the outcome, TAP may eventually expand its capacity.

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South & Southeast Asia HAZLI SHAM KASSIM President, Malaysian Gas Association, IGU Regional Coordinator

Natural gas vital for clean energy transition in Southeast Asia Southeast Asia requires energy to prosper On average, the GDP per capita of Southeast Asian Nations or ASEAN is approximately $4,742. Data from 2018 shows that nearly 30mn people are without access to electricity and approximately 219mn people do not have access to clean cooking in Southeast Asia. In order to expand energy access, grow its economy and ensure shared prosperity, ASEAN is expected to double its total primary energy needs by 2040.

Natural gas to fuel economic growth in ASEAN According to the ASEAN Energy Outlook, under the PHOTO: ISTOCK.COM/DROPSTOCK

Sustainable Development Goal (SDG) scenario to fulfil SGD7 in providing access to affordable and reliable energy, the region requires 32% coal, 24 % oil and 21% gas in its total primary energy supply in 2040. With both utilities and financial institutions committing to no longer be involved in new coal plant projects, the responsibility is left to natural gas to take over the role vacated by coal as baseload energy towards 2040.

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With natural gas featuring more prominently in the energy mix, CO2 emissions are expected to reduce in tandem with a reduction in coal consumption.

Natural gas a vital enabler in ASEAN hydrogen roadmap In October 2021, ASEAN Centre for Energy (ACE) released

In March 2021, the Energy Commission Malaysia released its Report on Peninsular Malaysia Generation Development Plan 2020-2039. According to the plan, a total of 14.2 GW of new combined cycle gas turbine (CCGT) plants will be commissioned

a study entitled Hydrogen in ASEAN: Economic Prospects, Development and Applications, which aims to support ASEAN in improving the coherence between its energy and climate policies and contribute to more climate-friendly development of the energy sector. Natural gas is expected to be the critical enabler as outlined in the following general roadmap for hydrogen energy development in ASEAN as recommended by the study:

between 2021 and 2039, whilst a total of 9.8 GW of

– Phase I: (2020-2025): Develop grey hydrogen production

gas-fired power plants will be retired. The plan also

and export capabilities and capacities at countries with

considered a total of 2.8 GW new coal-fired plants to be

existing natural gas resources and infrastructure, so as

commissioned and 7 GW to be retired during the same

to achieve economies of scale and prepare for the next

period. The plan envisages a total of 7GW of renewable

phase of hydrogen energy development.

energy (RE) and battery storage being added to the capacity by 2039. As Malaysia transitions towards a low-carbon economy, a combination of RE and gas is expected to enable the

– Phase II: (2026-2030) After the capacity and infrastructure are built for grey hydrogen production, shift to blue hydrogen production and exports. – Phase III: (2030 onwards) After the LCOE of renewables

power sector to play its part by reducing its carbon

significantly declines and the share of RE power

intensity by more than 60% by 2039. During the same

generation has reached high levels, expand green

period, demand for natural gas is expected to increase

hydrogen production and exports, leveraging on the

from 643mn ft3/day in 2021 to 1,656mn ft3/d in 2039.

hydrogen infrastructure developed during earlier phases.

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PHOTO: PETRONAS

Natural gas to support carbon neutral ambition: the Malaysian Example

R E G I O N A L U P D AT E

North East Asia & Australasia

into a jump in electricity bills amid the country’s scheme to wean away from coal and nuclear-powered generation. In Australia, east coast gas-use for power generation was up

GRAEME BETHUNE Chairman, Australian Gas Industry Trust, IGU Regional Coordinator

8% yr/yr in the second quarter on the back of a fire at the Callide coal power station in Queensland and floods affecting the Yallourn coal power station in Victoria. In New Zealand, lower generation from renewables due to a dry year and lower gas production have meant record coal

Rebounding gas demand in North Asia

imports for electricity generation. On August 10, load shedding left about 20,000 households across the country without power as renewable sources of power generation proved

Gas demand rebounded strongly across North Asia in the

unreliable in cold stormy conditions. The power blackouts

second quarter of 2021 as economies recovered from the

illustrate the growing energy shortage New Zealand has been

depths of COVID-19 lockdowns in 2020. Chinese gas imports

grappling with this year (reflected in high spot electricity and

(LNG and pipeline gas) were up by a massive 28% from a year

gas prices), and threatens to worsen in future due to a range of

earlier. China imported more LNG than Japan, historically the

government climate change policies designed to aggressively

world’s largest LNG importer. LNG imports by Japan, Chinese

reduce the production and use of natural gas.

Taipei and Korea grew by 4%, 8% and 9% respectively.

Gas playing a critical role in maintaining energy security

Regional gas market transitions to meet Paris goals The region’s energy sector is facing an unprecedented

Strong Chinese gas demand has been driven by the strong

transformation because of political, technological and

economic rebound from the coronavirus and power

market developments arising from the imperative to achieve

shortages amid extreme summer weather, lower renewable

net zero by 2050.

generation and strict limits on coal usage. Only 3.2% of China’s power was gas-fired in 2020, with 63% generated

Japan, China and Korea have recently declared their

from coal and the remainder from nuclear, hydro and

commitment to net zero and are demanding stable and

renewables. However, according to Wood Mackenzie, gas-

affordable carbon-free energy.

fired power generation jumped 14% year/year in the first four months of this year. Hydro generation in southwest China has

There are already carbon-neutral LNG cargoes being shipped,

been curtailed by lower rainfall and solar output that was

mostly to Asian buyers. Between June 2019 and April 2021

lower than expected, with the Guangdong province rationing

there were 14 carbon-neutral cargoes, 12 for Asian buyers,

power. At least nine provinces have said they are dealing with

including at least four from Australia.

similar issues. LNG projects increasingly have carbon capture and storage KOGAS is reported to have signed a long-term contract

(CCS) facilities. The Gorgon LNG project in Western Australia

with Qatargas for annual LNG supplies of 2mn metric tons

is one of the biggest CCS projects in operation. While the

from 2025 until 2044 amid growing concerns about supply

project has suffered delays, the operator Chevron, has said it

insecurity and the spike in LNG prices that could translate

has injected around 5mn mt of CO2e since starting injection in

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R E G I O N A L U P D AT E

August 2019. The project, reported to have cost $1.5-$2.2bn,

markets and numerous medium and long-term hydrogen

is one of the few decarbonisation projects to be largely

projects of a global scale coming to fruition.

privately funded. The project received a $45mn Australian government grant but otherwise has been completely funded

Australia’s first green hydrogen production plant recently

by Chevron and its two partners, Shell and ExxonMobil.

opened in South Australia, putting 5% of hydrogen into the gas stream for 700+ households and selling hydrogen to BOC,

Hydrogen rising An important way of achieving the Paris goals is through development and commercialisation of hydrogen, either through blue hydrogen produced from natural gas with CCS or green hydrogen produced from renewables. There is strong interest in hydrogen throughout the region. For example, plans to use hydrogen as part of future energy systems have seen demand estimates of around 4mn mt of Australian hydrogen by 2030. Hydrogen could be Australia’s next great export, and Australia is in a very strong position to meet market demand. Strong demand for internationally traded hydrogen is anticipated which has seen Australia fast track many of its hydrogen projects. Australia currently has nearly 50 hydrogen projects being trialed. Australia has many of the pre-requisites needed to support a large hydrogen export market now and into the future; including an abundance of natural resources, strong industry commitment, advanced capability, existing infrastructure, lots

one of Australia’s biggest industrial gas suppliers. Meanwhile, the 15-GW Asian Renewable Energy Hub, which is the world’s largest wind-solar hybrid project, plans to generate massive volumes of renewable energy to produce green hydrogen and ammonia for export.

Energy transition must be achievable… just look at Japan A successful energy transition will deliver clean, secure and affordable energy, and gas is crucial to this. While the various nations across the region work towards their net zero commitments, gas will still play a central role as a critical energy source. Japan has recently released its Sixth Basic Energy Plan. Japan acknowledged the important role of gas in realising its efforts to decarbonise power generation. Japan is hoping to expand the use of gas as a major raw material for carbon free hydrogen and ammonia and will use the existing natural gas pipelines and other infrastructure to do this.

of open space and the right political levers in place to produce

Japan will continue to import LNG and expects that in 2030

blue and green hydrogen. Australia is one of the world’s largest

around 20% of its primary energy supply will still come from

exporters of LNG and can easily leverage this position.

natural gas.

Australia is also well situated to take advantage of CCS

Japan also aims to expand its market by trading 100m mt/yr

technologies to produce low-emissions hydrogen from natural

of LNG within Asia.

gas. Carbon capture rates of 90% or more will likely be required, and this is technically feasible in Australia.

Hydrogen ready for today and tomorrow

Gas offers the fastest and most economic path to reduced carbon and air pollutant emissions; helping to meet new energy demand, while improving the environment, air quality, and living conditions across the region.

Strong government and industry investment over the past

A stable energy supply is paramount to regional economic

5 years has seen Australia become a leader in blue and

growth and development and is a building block for reliable,

green hydrogen production, the development of new energy

sustainable and affordable energy systems.

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A sustainable flame:

the role of gas in net zero

The role of gas as the second pillar of decarbonisation needs to be elevated

MICHAEL STOPPARD, Chief Strategist Global Gas, Climate & Sustainability Group, IHS Markit

eep and fast are becoming the imperatives of environmental policy. Deep, as governments and corporations are setting increasingly ambitious targets

for greenhouse gas emission cuts. Fast, as recognition grows that the rate of progress in emission reduction is falling short of what is required to stay within manageable warming levels. To address the challenge, many different technologies and policies will be required, and gas—in its many forms-- has an important and unique role to play, a role that needs to be more widely recognised. Gas can help in a variety of forms as regular natural gas, biomethane, hydrogen, ammonia and synthetic natural gas. The benefits of natural gas have been stated many times— clean burning properties, relatively

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Figure 1: Acting early reduces emissions

Annual emissions

Global energy-related GHG emissions(2019)

37 gigatons

Drivers of early emissions reduction using gas

Avoided emissions by taking early action

• Coal to gas substitution • RNG blending • Early-stage projects in low-carbon

Net zero

ammonia, hydrogen, and CCS

Time

low carbon emissions, proven technology, widespread

trajectory of emissions cuts determines temperature

availability, and relative affordability. Some of its

rise, and early cuts can help later efforts. So, we

drawbacks are also well documented including

need to maximise the technologies at our disposal

most critically the need to manage and minimise

today and not wait for new technologies to scale

methane leakage. No solution is perfect, but too often

up. (See Figure 1). This is why most simulations of

policymakers are making the perfect the enemy of

global energy to achieve the Paris climate goals or

the good. Policy now needs to recognise that gas can

net zero show natural gas demand either remaining

play a critical role in the energy transition becoming

flat or growing out to 2030, recognising its short

the second pillar alongside renewable power toward

term benefits. (See for example the IHS Markit

fast and deep decarbonisation. A new report from IHS

Low Emission Cases “MultiTech Mitigation and

Markit seeks to explain the contribution that gas can

Accelerated CCS”)

make towards decarbonisation, and also to highlight its limitations.

Natural gas has already demonstrated its effectiveness in reducing emissions quickly and at

Fast decarbonisation

scale through substituting for high emitting fuels,

Much policy is now focused on 2050 as a target in

mainly coal. This was a major driver of cuts in Europe

many developed economies for achieving net zero.

and more recently a similar impact has happened

Target dates are helpful to frame plans. And it needs

in the US. Yet under-utilised gas-fired power plants

to be recognised that the energy complex is not

exist across OECD markets where substantial coal

capable of complete overhaul overnight—assets

burn continues—whether in the United States,

lives, lead times, and the scaling-up of new supply

Europe, Japan, or South Korea. Further substitution

chains are simply too long.

is possible quickly and with limited capital investment

However, speed also matters. The overall carbon

in downstream infrastructure.

budget—the total cumulative amount of emissions—

And there is a potentially bigger prize to be had

is at least as important as any target end point. The

in the growing markets of non-OECD Asia. Renewable

G L O B A L VO I C E O F G A S

O C TO B E R 2 0 2 1

No solution is perfect, but too often policymakers are making the perfect the enemy of the good.

power with its enlarged supply chains and lower

and green hydrogen is much debated–but either

costs will play the central role in changing the Asian

way hydrogen can supplement and ultimately

generating portfolio, but that cannot suffice alone.

supersede natural gas over time.

Substitution from coal toward natural gas can be

• CCUS capacity is projected to capture up to 1.5–8

done relatively quickly, requires limited deployment

Gt of annual emissions in 2050, a significant share

of capital, and has a significant impact on emissions.

of the total 37 Gt of energy–related emissions

The IHS Markit study A Sustainable Flame

today. A high proportion of the CCUS will be

estimates that a cost-optimal pathway for emission

dedicated to factories that run on natural gas.

reductions in the Asian power sector would require a

It would enable high process heat industries to

combination of renewable power and natural gas. An

continue running on natural gas while generating

increase of 420–550bn m3/year of additional natural

further deep emission cuts.

gas—10–15% of current global consumption—would be required, delivering between 0.9 and 1.2 gigatons

Low-carbon gas technologies are at a critical

(Gt) of annual carbon dioxide (CO2) reductions. For

juncture. Both low-carbon hydrogen and CCUS have

this to happen, changes are needed in downstream

reached the point where they can be developed

policies and carbon pricing. The high natural gas

commercially where strong carbon pricing incentives

prices of 2021 highlight the need to encourage

exist such as in Europe and California or with

development of more supply—resource availability is

the support of policy incentives such as the 45Q

not the issue.

tax credit in the US. IHS Markit finds that many applications for these technologies work with

Deep decarbonisation

carbon price support of $40-60/metric ton, close

Unabated natural gas can take us so far. For deeper

to levels in some markets today. Early deployment

decarbonisation both carbon capture, utilisation, and

of these technologies will bring costs down as the

storage (CCUS) and hydrogen have the potential to

industry scales up and will start to build up the

make a huge contribution. They can support in areas

supply chains required for what are essentially new

where direct electrification is difficult or impossible.

industries. (See Figure 2)

• Low-carbon hydrogen use is projected in some net-

Infrastructure as the key enabler

zero outlooks and roadmaps to reach anywhere

While the fuel switching advantages of natural gas

between 10% and 25% of the global energy

are often recognised, some express concern that

mix by 2050 from almost nothing today—an

these investments may embed or lock in future

extraordinary undertaking. The hydrogen may be

emissions for several decades. But these “lock-in”

generated from natural gas with carbon capture

concerns need not be the case because the

or from renewable power – the split between blue

infrastructure can be repurposed.

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Figure 2: Range of CO2 abatement costs using gas to reduce carbon emissions Industry

Steel production

Power generation

Power generation: New build

Transport

Power generation: Existing Transport: Trucks

Carbon price (2021): Average

Steel production Ammonia production Hydrogen production Power generation New build Transport: Trucks 40

100

120

US$ per ton of CO2 abated

• Pipelines—both transmission and distribution—

performance standards with limits on the life that the

can in an early stage blend in ‘green’ gases to

asset can operate before being converted. This is the

lower the carbon footprint, while in the longer

route both to reap the early benefits of natural gas

term they can be repurposed for shipping of 100%

use and to address the concern of emission lock-in.

hydrogen. So too with gas storage infrastructure • Gas-fired power plants can convert to run on

The second pillar of decarbonisation

hydrogen or sustainable ammonia, or in some

We need to recognise three key take-aways. First,

circumstances can retro-fit CCUS

natural gas can make a meaningful impact in the short

• Liquefaction plants can be converted to liquefy

term; second, low carbon gases will be critical longer

hydrogen, likely at a lower cost than building a

term; third, encouraging natural gas in the short-term

liquefied hydrogen plants from scratch

need not lock-in emissions or jeopardise longer-term

• Industrial and domestic gas boilers can be

targets since natural gas infrastructure can provide

manufactured to be readily adaptable from

the transition from fast to deep decarbonisation. The

natural gas to hydrogen

next step for gas—already under way—is to better

• LNG-fuelled engines for marine transportation could be later converted to run on ammonia

our understanding of the technological options and costs throughout the value chain of this transition from unabated natural gas to low carbon gases.

Using existing infrastructure much of which is hidden underground is a huge advantage. Repurposing will often

The role of gas as the second pillar of decarbonisation needs to be elevated.

be more achievable than the alternative of permitting and building significant new power transmission lines in an all-electric wires world. Repurposing infrastructure has technical challenges but the costs, while significant,

A Sustainable Flame: the role of gas in net zero is a nine-

are still lower than building new facilities.

month research programme undertaken by the Climate

The option of repurposing can provide flexibility

& Sustainability team within IHS Markit. More than 30

to policymakers and lenders. They could structure

corporations and governments representing all parts

authorisations and loans such that any new-build

of the gas value chain participated in the process. The

infrastructure be conversion-ready and have defined

Summary policy White Paper is available here

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Clean technologies that will make gas and gas use emission-free Low carbon gas technology costs are coming down, offering an expedient, achievable, and secure route to decarbonisation, but policy support and access to capital are needed to accelerate innovation and scale up deployment sufficiently to meet the Paris Agreement goals.

ow carbon gas technologies – renewable gases (RG), hydrogen and carbon capture and storage (CCS & CCUS) – all deliver major reductions in greenhouse gas (GHG) emissions. They have

been featured prominently in nearly all modelled scenarios for achieving the goals of the Paris Agreement on Climate Change. Moreover, they are all proven and technically viable today and, in some contexts, even cheaper than the electricity-based alternatives.

TATIANA KHANBERG, Senior Manager Public Affairs, International Gas Union

However, further technological innovation and greater scale are required to capture the enormous value of these solutions in a just transition to a sustainable future. That in turn requires government support, addressing gaps where markets fail or haven’t yet developed and introducing market-based mechanisms that facilitate the development, commercialization, and scaled deployment of these clean technologies. The toolbox of effective policy measures is diverse and well documented, with many successful case studies from around the world. From mandates, like the low carbon fuel standards to production

G L O B A L VO I C E O F G A S

O C TO B E R 2 0 2 1

incentives, like sensible feed-in-tariffs, or competitive

promise further efficiencies and cost reductions,

procurement programs – like some jurisdictions

if deployed at greater scale. As we show in our

have developed for renewables. In Denmark, for

2020 Gas Technology and Innovation Report with

example, the use of feed-in tariffs has enabled RG

BCG, cost projections estimate that scale and

production to reach 10% of national gas supply, a

learning effects could reduce the capital costs of RG

figure expected to rise to 30% by 2030.

production by 45% to 65% and operational costs by 10% to 20% by 2050.

Renewable Gas. Its full potential as yet untapped

CCUS – carbon capture, utilisation & storage

Renewable gas, also called biogas, is produced by

Renewable Gases’ full emissions abatement potential

capturing the methane released from the breakdown

could be reached through combining with CCUS. This

of organic material or through thermal gasification

creates two carbon sinks – the use of feedstocks

processes using solid biomass (i.e. garbage). These

which absorb carbon from the atmosphere, and

technologies show the greatest range of potential

then long-term sequestration of the carbon released

net GHG emissions reductions relative to natural gas

during combustion. Combining bioenergy with CCS is

combustion. When best practices are applied, RG

known as BECCs.

can achieve emissions reductions of 80% and higher. They can even bring a net negative emission balance,

reductions from CCUS range from 4 to 7 gigatons by

as they capture and use the methane that would

2050, but achieving this will require a step change in

have otherwise escaped into the atmosphere.

investment levels as capacity will need to increase by

However, the full versatility of RG remains unexploited. Upgrading biogas – the initial product

somewhere between 140 to 216 times. The CCUS sector is already demonstrating

from the decomposition or gasification of organic

a downward cost trajectory. For solvent-based

materials – to biomethane creates a product directly

capture new types of solvents and process designs

interchangeable with natural gas. As a result, low

have improved efficiency by up to 50%. Innovations

carbon gas can be fed directly into the existing gas

in carbon capture technology have the potential

grid, with no additional infrastructure investment nor

to reduce the capture costs for more dilute CO2

any changes to end-use appliances.

streams to less than $50/mt of CO2 avoided.

Six different processes have been developed for biogas to biomethane conversion, all of which

Estimates of the potential scale of GHG emissions

G L O B A L VO I C E O F G A S

In addition, new approaches to oxy-fuel processes – burning natural gas in a high oxygen environment

O C TO B E R 2 0 2 1

– improve combustion efficiency and provide a pure

Market building policy measures, infrastructure

CO2 stream. This could transform the economics of

investment and R&D support for core clean hydrogen

CCS combined with gas-fired power generation.

technologies would stimulate new markets for the

In processes which produce concentrated CO2

fuel, ensuring its viability.

streams, CCS projects started becoming viable at a carbon price of $35/mt, but many barriers remain

Cost competitiveness

which require regulatory solutions. For example,

Estimates of the costs of low carbon gas technologies

regarding the rules for the transportation of CO2,

vary widely – some forms of low carbon hydrogen and

permitting underground storage sites and management

RG are seen to be already competitive with unabated

of the long-term liabilities relating to storage.

natural gas in particular areas, while others, like CCUS plus natural gas combustion, would require a carbon

Blue Hydrogen

price of $50/mt or more to be competitive. However,

Hydrogen produced from natural gas plus CCUS has

even these higher cost low carbon technologies are

the potential to achieve emissions reductions of up

more competitive compared with other alternatives of

to 90% relative to unabated natural gas. Overall, to

achieving low or near zero emissions.

date, CCUS has demonstrated the ability to reduce full value chain emissions by 50-80%. Steam reforming natural gas with CCUS is

For example, in high heat applications in industry hydrogen and CCUS have been shown to be the most cost-effective way of reducing GHG

the lowest-cost route to low carbon hydrogen

intensity. Electrifying high temperature processes in

production. The other primary option is using

industry is very costly because of the required heat

electrolysis powered by renewable energy.

intensity and high energy consumption of industrial

Electrolyser costs are falling, but heavy use of large

applications. All three low carbon gas technologies

amounts of electrolyser capacity would undermine

are suitable outcomes here.

the common assumption that they would run only on excess, essentially free, renewable electricity. Meanwhile, methane cracking is an emerging

Similarly, in the building sector, low cost sources of RG, produced from waste, are cost competitive with electric heating in cold climates

technology with promising potential. Using either

or commercial applications. This is particularly

catalysts or a thermal process, methane is cracked

relevant in countries with high power prices

to produce hydrogen and carbon in solid form rather

and heating requirements and with established

than as a gas which could escape into the atmosphere.

gas infrastructure. A lack or underdevelopment

This method is also known as methane pyrolysis.

of natural gas infrastructure is a barrier to the adoption of low carbon gas technologies.

Natural Gas Infrastructure is Key

In transport, RG and hydrogen are already

Existing natural gas pipelines can take blends of

competitive with electrification, particularly in heavy-

methane and hydrogen of between 5% to 15%

duty applications, owing to batteries’ ratio of energy

hydrogen without additional investment, while end-

output to incremental weight.

use appliances work on blends up to 20%. methane, by adding carbon, would allow unlimited

Policy Should Support Gas Clean Tech, Not Undercut It

import into the existing gas system and is a key area

Gas technologies are already playing a key role

where support for innovation could reduce costs

in facilitating a sustainable energy transition –

to facilitate the uptake of low carbon hydrogen.

enabling greater shares of renewables, providing the

Meanwhile, converting hydrogen to synthetic

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“ Further technological innovation and greater scale are required to capture the enormous value of these solutions in a just transition to a sustainable future.” — Tatiana Khanberg, Senior Public Affairs Manager, International Gas Union

necessary flexibility for systems under greater stress

including renewable gas, hydrogen, and carbon

from extreme weather events, and dramatically

capture, utilization, and storage (CCUS) provide

cutting emissions when replacing coal and oil – and

an efficient and cost-effective pathway to

further innovation in the sector can significantly

dramatically reduce GHG emissions. These

enhance benefits for the environment and human

technologies are particularly relevant for

development in three ways.

sectors where emissions are difficult or very costly to abate through other means. They

1. Today, switching to natural gas from coal or oil products would immediately reduce emissions,

can also capitalise on the use of existing gas infrastructure to minimise capital investment.

both in the form of GHG emissions and localized air pollutants. At the same time, gas technologies

There are undeniable benefits and a robust

can improve global access to clean, modern

case for continued investment in sustainable

energy, including for the world’s poorest.

natural gas development and infrastructure, along with clean gas technologies that provide a solid

2. Continuously into the future, gas technologies

pillar for the decarbonisation of the energy system

through continued development and deployment

– from power to heating/cooling and industry and

of cost-effective and highly efficient technologies,

transport, and cooking.

natural gas can continue to facilitate bigger and

Last year, together with the BCG, we produced an

faster integration of renewables, while further

in-depth analysis of the specific gas technologies, the

reducing both the emissions and costs. In areas of

cost-effective deployment of which to their economic

the world where energy systems are developing in

potential would cut energy sector’s emissions by a

a decentralized manner, natural and low carbon

third by 2040. Much of that analysis remains highly

gas technologies can enable distributed energy

relevant today, and the investment case has only

systems and increasing efficiency of energy

grown stronger in today’s environment of a growing

consumption. (think CHP, small scale LNG, micro

inequity in the world, cost pressures, and the risk of

turbines, etc.)

falling back on coal when gas becomes unaffordable from lacking investment, with renewables only able

3. Progressively deeper into decarbonisation, low- and zero-carbon gas technologies–

G L O B A L VO I C E O F G A S

to deploy at a given rate and meet a given portion of demand.

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The road to net-zero:

GECF’s perspective A

head of the crucial UN Climate Change Conference (COP26) this November, HE

Yury Sentyurin, General Secretary of the Gas Exporting Countries Forum (GECF), discusses with Global Voice of Gas the role that natural gas should play in delivering on the net-zero emissions goal

What are the GECF’s views on the IEA’s recent net-zero emissions scenario?

YURY SENTYURIN, General Secretary of the Gas Exporting Countries Forum

consumer demand, the expectation is that GHG emissions will rise by 2% compared to last year. It should be noted that 75% of GHG emissions are related

It is a fact that worldwide emissions have skyrocketed

to the energy sector, prompting many governments

in recent years. Between 2000 and 2019, greenhouse

and major energy companies to commit to be carbon-

gas (GHG) emissions have grown by 39%. In 2020, due

neutral over the next three to four decades.

to the COVID-19 lockdowns, emissions dropped by

In this light, there is no arguing that doubling

almost 2.6bn metric tons of CO2 compared to the 2019

down on efforts to reduce GHG emissions and

level. In 2021, as we witness success in vaccination

shifting toward sustainable use of our world’s natural

programmes around the world and recovery in

resources are paramount to humanity’s survival and

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This is an issue of a one-size-fits all approach to mitigating climate change. — Yury Sentyurin

prosperity. However, reports such as the International

transport sector. Many questions arise here, such as

Energy Agency (IEA)’s Net Zero by 2050: A Roadmap

sources of the required electricity, grid capacities,

for the Global Energy Sector are not grounded in

costs, readiness and capacity of countries to produce

reality and rather based on wishful thinking. The IEA

and use EVs, as well as how to incentivise citizens to

report, published in May, encompassed 400 sectoral

switch to EVs whilst upholding their consumer rights.

and technology milestones, in which coal, natural gas and oil demand should fall by 90%, by 55%, and 75%, respectively, to achieve a net-zero target by 2050. This

or carbon capture, utilisation and storage (CCUS)

is highly impractical and unrealistic. The expectation

technologies, drawing on the idea that at least 4bn

that the IEA has from the fossil fuels would require that

metric tons of CO2 and 7.6bn mt of CO2/year should be

its other curated 400 milestones be met as well, which,

captured and stored by 2035 and 2050, respectively,

again, is unlikely to happen in many parts of the world.

which is up from the current level of around 40mn mt

Another major oversight of the report is that the

of CO2/yr. However, the question arises when we think

differentiated approaches between developed and

about the scale and the cost of technology. Currently,

developing countries are not considered. We know that

there are only around 20 commercial CCUS operations

countries are at different stages of development and

worldwide. The CCS/CCUS technology remains highly

they have different energy resources. The whole world

expensive and is still unable to compete with regular

is not comprised only of North America or northwest

coal, gas, wind and solar power plants. Essentially, the

Europe. The bulk of the GHG emission growth,

carbon prices are not high enough to make the CCS/

currently, originates from China, India, and Africa. And

CCUS technology economically viable.

indeed the path to decarbonisation for these countries

Last but not least, the report doesn’t take into

is different than the more economically mature regions.

account future negative emission technologies, as well

In another report, the IEA itself mentioned that the

as the offsets from outside the energy sector. These

number of people without access to electricity in 2020

are likely to happen in the future and are necessary for

was about 786mn, and that more than 2.3bn people

the future development of fossil fuels.

still do not have access to clean cooking, mostly in

Furthermore, the IEA’s net zero scenario relies on the use of carbon capture and storage (CCS),

Suffice to say that the IEA net zero emission

Africa. Despite these painful numbers, the IEA goes on

scenario represents an extremely challenging pathway

to assume in its net zero scenario that a population

to achieve zero emissions and its assumptions seem

without basic access to electricity and clean cooking

overly ambitious. This raises several questions on the

will reach the point of reset by 2030. How this dramatic

scale of investment, land availability, the expansion of

and unrealistic shift happens is not expanded by the IEA.

the electricity grid as well as international cooperation.

The Net Zero by 2050 also sees a global policy

An aggressive expansion of renewables, in particular,

that ends sales of new internal combustion engine or

could generate a debate over the inevitable extensive

ICE vehicles by 2035 and boosts electrification in the

land use. However, even the most vocal proponents of

G L O B A L VO I C E O F G A S

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renewables fail to explain how and when the world-at-

all. Nations utilise their available resources to meet

large can access all this clean and affordable energy.

the energy needs of their populace, ensure energy

In addition, the current level of technology is not

security, affordability, and an environment that will

yet sufficient to achieve the proposed targets by 2050,

nourish its communities. Recent short-term events

especially for developing countries, and we do not

point to the need for integration between energy

condone energy policies and directing investment

sources to ensure a stable energy supply. For

resources towards expensive decarbonisation

example, overreliance on wind complicated the energy

options and technologies, some of which are yet to be

system in some countries as the backup was not

proven. Therefore, it is premature to accept the IEA’s

available when the wind stopped. However, reliable

resounding statements as an indisputable plan toward

integration with natural gas and other sources could

carbon neutrality.

have fixed the shortfall. The only way to de-risk the

I should add that in our view any successful

consequences of hurriedly rolled out energy systems

discussion on promoting decarbonisation initiatives

is to explore the available energy options, reassess

rests in finding a balance between achieving GHG

their development, and apply in the right context. This

emission reduction targets and energy security and

should be followed by discussion with international

economic growth. We should not write off hydrocarbons

partners to optimise and learn.

due to their availability, affordability and remarkable contribution to improving energy access and economic conditions. Specifically, natural gas is one of the global

To what extent can gas be viewed as a solution to the climate change problem?

enablers for reducing emissions uninterruptedly and steadfastly by replacing carbon-intensive fuels and

Any fuel or technology has its own positive and

backing up intermittent renewables. At the same time, the

negative impact on climate change, but the magnitude

emission mitigation potential of natural gas will increase

of the impacts are different. For example, even

with a larger deployment of decarbonisation options,

renewable energies such as wind and solar that are

including carbon capture and sequestration technologies,

assumed to have a tremendously positive effect on

production of hydrogen and ammonia from natural gas.

reducing climate concerns have certain emissions

This is an issue of a one-size-fits-all approach to mitigating climate change. One size does not fit

G L O B A L VO I C E O F G A S

associated with the manufacturing of the materials and instruments to manifest these energies. However, in

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Recent short-term events point to the need for integration between energy sources to ensure a stable energy supply. — Yury Sentyurin

such cases that the best example is renewable energy carriers, the advantages outstrip the disadvantages.

The IEA’s Net Zero by 2050 report argued a very challenging and controversial statement of no new

Natural gas is the cleanest fossil fuel that offers

investment in new fossil fuel supply – including oil and

varied benefits for sustainable future energy systems.

gas – after 2021. The IEA assumes to counterbalance

Renewable energies, and the electricity produced from

such moves with substantial investments in

them, have not been and will not be adequate to meet

renewables; in clean energy investments from the

the global energy demand. And in varied sectors such as

last five years’ average of $1 trillion up to $5 trillion

heavy transport and high-grade temperature industries

annually by 2030. The major advanced economies are

they can not meet the convenience and standard of

showing positive results on this trend by aligning the

being a proper energy carrier. So molecule energy carrier

relevant policies and financial institutions’ capabilities.

is an undeniable need of the future energy landscape,

At the same time, for developing Asia and Sub-Saharan

and natural gas emerges as a key player. Substitution

Africa this poses a serious challenge. On one side,

of coal and oil products for natural gas can bring many

we see the divestment moves by global oil and gas

advantages and abate a high level of emission as we have

majors from fossil fuels, and on the other side we

witnessed in countries such as China.

are witnessing the reluctance of global financial

Hydrogen too can play a role in providing the molecule energy carrier and reduce emissions. It can be extracted from natural resources as is being done

institutions to invest in renewables in Sub-Saharan Africa and developing Asia. Combatting global energy poverty by 2030,

for oil and natural gas. Hydrogen can be produced

especially on the African continent and elsewhere, will

in different ways, of which two promising pathways

require developing countries to embrace a balanced,

are blue and green hydrogen. Blue hydrogen refers

inclusive and perhaps differentiated approach to

to the technology of natural gas reformation with the

tackling the climate change agenda and to secure

implementation of CCUS. In other words, the carbon

natural gas supply investment on a sufficient scale to

content of the fuel is captured before the combustion.

support the sustainable levels of growth.

In our opinion, blue hydrogen is a pathway that reduces

Restricting investments into Africa’s natural gas

any perceived disadvantages of natural gas whilst

industry will have a limited impact on the global

offering other advantages to the world’s energy future.

carbon emissions as, for example, Sub-Saharan Africa accounts for the smallest share of global energy-

Is there a risk of under-investment in natural gas supply?

related CO2 emissions at 3% only. On the contrary, it may adversely impact the continent’s economic prospects and future as natural gas is one of the

The risk of under-investment in natural gas supply is

central energy pillars to eradicate energy poverty

one of the key topics of current global debate and

within the continent and expand its LNG exporting

one of the core concerns of suppliers as well as of

potential to support the budgets and the economies of

consumers of natural gas.

the most vulnerable nations.

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Let us make an attempt to distinguish two

So if governments follow the approach outlined

separate phenomena: market seasonality and market

in the IEA’s net zero scenario and there is no further

fundamentals. The market seasonality and the short-

final investment decisions (FIDs) for new unabated

term supply disturbance events were and will drive

coal plants, this would create a significant shortfall

the market up and down. However, the fundamentals

in production levels over the short- to medium-term,

of the gas market are indicating that more consumers

causing high volatility in the oil and gas market and

are getting into the market and the design of country-

damaging the security of demand and supply. We may

specific energy transition is pushing countries to

end up witnessing high oil and gas prices and the world

increase their demand for natural gas. For example,

economy may be severely impacted.

the LNG demand in the first half of 2021 is higher than

The other aspect worth noting from my point of

that of 2020 and 2019. These facts compel the need for

view is the way that the IEA looked at natural gas

sustainable natural gas investment to meet the demand

and clean fuels. It is common knowledge that natural

growth that is happening and will likely continue in the

gas is a viable, low-cost abatement option to provide

future. We see natural gas investment is picking up

affordable, reliable, and clean energy to all societies.

with IOCs entering areas where they did not operate

Therefore, an energy transition without natural gas is

before in Africa and the Asia Pacific while NOCs are

impossible to happen, in particular in Asia and Africa,

showing determination to expand their existing natural

which are highly dependent on cheap fuels. Even if

gas investment and liquefaction facilities to supply their

countries would like to follow the IEA’s hydrogen

consumers. Marketing for the idea of under-investing

milestone, you would need gas for the transition

will harm both consumers and producers and could

period of producing by-products such as blue

drive energy prices to historical levels.

hydrogen and ammonia. It is unlikely that governments will take IEA’s net

What risks do you envision if the IEA’s net-zero roadmap will be followed?

zero scenario as a prescribed trajectory, and this could instead create some uncertainty in the energy sector. The potential energy security risk is manifold,

First of all, there is no practical way to force any

for both producers and consumers, whilst a shortfall

country to stop producing or consuming fossil fuels,

in investments in the gas and oil industry could

in particular oil and gas, which are an indivisible part

affect stability in energy markets, possibly leading to

of the world energy mix. However, it might be possible

economic insecurity and geopolitical tensions.

that only the OECD countries – barring, for instance,

GECF Global Gas Outlook 2050, which in the

steps mentioned in the IEA’s 2050 roadmap.

reference case implies a more pragmatic approach,

It is also true that many energy policymakers and

global primary energy demand will rise, boosted by

major oil and gas companies are addressing the IEA’s

cumulative economic and population drivers amidst

scenarios as part of their future business plan.

higher living standards, growing prosperity, and better

At the heart of many fundamental issues that the

According to the latest projections in our flagship

Turkey, Italy, and Greece – will consider some of the

access to energy in some regions. Natural gas and oil

IEA’s report fails to address is another unanswered

will provide more than 50% of global energy demand

dilemma: the source of investments that are needed to

in 2050. Thus, a multi-dimension approach should be

achieve the net zero targets. Because on one hand, the

the way forward to deal with the climate challenge

report calls for no new investments in oil and gas projects

in which the oil and gas industries form the bedrock

beyond 2021, and on the other hand the industry which

of the solution, contributing to economic growth and

generates capital investment is barred from developing.

social vectors.

G L O B A L VO I C E O F G A S

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Where energies make tomorrow

Accelerating the energy transition for a better tomorrow Technip Energies is a leading engineering and technology company for the energy transition. We are frontrunners in LNG, hydrogen and ethylene with growing market positions in sustainable chemistry, CO2 management and carbon-free energy solutions. In LNG, we deliver first-class projects while offering solutions to reduce CO2 emissions from liquefaction and export terminals. Through our extensive portfolio of technology, products and services, we bring our clients’ innovative projects to life while breaking boundaries to accelerate the energy transition for a better tomorrow.

technipenergies.com

Gas in their sights:

The fuel’s place in net-zero strategies A number of countries see natural gas and hydrogen as key components of their decarbonisation strategies, at least in the shorter and medium term, as they PHOTO: ISTOCK.COM/OLEKSANDER BUSHKO

pursue net zero ANNA KACHKOVA

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growing number of countries are

China – the world’s largest GHG emitter –

adopting long-term targets for net zero

is targeting 2060 for reaching net zero. If the

greenhouse gas (GHG) emissions as

country meets this goal, the impact would be

the pressure to accelerate the energy transition

significant, given that China is estimated to

grows. The details of how these countries plan

account for over 25% of global GHG emissions.

to reach their goals are often just beginning to emerge, and a debate is ongoing about the role

Gas solution

of gas in the energy transition. It is already clear,

Many of the countries that set net zero targets

though, that some countries see gas – both

still need to provide details on how this will

methane and hydrogen – as key parts of the

be achieved. For several, though, it is already

puzzle, at least in the short and medium term.

clear that natural gas and hydrogen will play a significant role in their decarbonisation

Net zero Net zero emissions goals are being adopted

This is reflected in broader global trends,

across countries and major regional players,

which show how gas demand has grown, global

such as the EU. Within the EU, some countries

pandemic caused disruptions seen in 2020

are aiming to reach net zero faster than others,

notwithstanding. Global natural gas consumption

while all being expected to contribute to the

fell by 2.3% year on year in 2020 owing to the

common goal of net zero emissions by 2050.

impact of the COVID-19 pandemic, according to

Finland leads the way, with a target of net zero

BP’s Statistical Review of World Energy. However,

emissions by 2035, followed by Austria and

the drop came after consumption had risen by an

Iceland – 2040 and Sweden and Germany – 2045.

average of 2.9% per year over the prior decade.

Most, though, have opted to keep 2050 as the

Looking ahead, consumption growth is expected

net zero target year on a national basis, in line

to resume. Management consulting firm McKinsey

with the EU goal.

& Co. said earlier this year that natural gas would

Many non-EU countries are also targeting net

be the only fossil fuel whose consumption would

zero emissions by 2050, including the UK, Canada

grow beyond 2030, peaking in 2037. Beyond that,

and, unofficially, the US. This year, US President

McKinsey anticipates that hard-to-replace gas use

Joe Biden announced that his country would

in the chemical and industrial sectors will limit

adopt a goal of cutting emissions by 50-52% by

the impact of an accelerating decline in gas used

2030 compared to 2005 levels. This would be an

for power generation. It forecast that this would

intermediate target set to pave the way for net

translate into a gas consumption drop of only 0.4%

zero by 2050. However, the country has yet to

between 2035 and 2050.

officially adopt the net zero commitment. Elsewhere in the world, Australia has resisted

strategies.

While some continue to dispute the role of gas in the energy transition, saying it should not

making a 2050 net-zero pledge, with Prime

even be a transition fuel, let alone a destination

Minister Scott Morrison saying recently that the

fuel, for others it is an obvious stepping stone

country would aim to reach net zero “as soon as

to decarbonisation and curbing air pollution, as

possible”. Like the US, though, Australia has an

power generation shifts from coal to gas. This is

intermediate target, aiming to cut its emissions by

particularly apparent in Asia, where demand for

26-28% below 2005 levels by 2030.

LNG is forecast to continue to grow thanks

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Gas will play a significant role in China, which is on course to become the world’s largest importer of LNG, overtaking Japan in large part to coal-to-gas switching in power

potential, and Equinor has said blue hydrogen

generation.

production could help keep Norwegian gas valuable

China is one of the first among the countries

in a low-carbon future.

where gas will play a significant role, on course

Another country embracing blue hydrogen is

to become the world’s largest importer of LNG.

Canada, which is grappling with the question of how

Coal, which still accounted for 58% of China’s total

it can sustain its oil and gas industry while pursuing

primary energy consumption in 2019, is set to take

net zero. Leading producers and other players in

the largest hit as the country decarbonises, opening

Canada’s oil sands have begun pursuing initiatives,

up further opportunities for gas. Additionally, China’s

both jointly and separately, to develop blue

overall energy demand is going to keep growing as

hydrogen hubs in Alberta, and have called for federal

the country’s economy continues to grow at a high

government support for these plans.

pace, making a rapid replacement of fossil fuels, that currently play a dominant part in the economy, all

Balancing act

the more challenging and unlikely.

Much could change between now and 2050, but for

In other countries, natural gas is expected to

there are intermediate decarbonisation goals to

a variety of technologies to deliver on the goals of

pursue, and the pressure to tackle climate change is

energy transition and Paris. Many examples can

ramping up rapidly. The challenge will be to balance

already be seen of hydrogen blending with natural

goals for shifting to renewables and decarbonising

gas in countries with existing gas pipeline networks,

with meeting gas demand, which is set to keep

such as Italy and the UK.

growing, at least in the near and medium term.

Additionally, blue hydrogen – produced from

most countries, net zero remains distant. However,

work in tandem with hydrogen as governments target

For those countries that have yet to move away

natural gas, with carbon capture and storage

from widespread coal usage, gas is certain to be

(CCS) – will play a key part in some countries’

necessary over at least the coming decade – it is

decarbonisation strategies. For example, the UK

a quick and cost-effective substitute, as gas plants

recently unveiled its hydrogen strategy, which

are overall less capital intensive and faster to build,

involves a twin-track approach supporting both blue

than coal. And for those that are incorporating

and green hydrogen – with the latter produced in

blue hydrogen into their plans, natural gas supply

an electrolyser using renewable energy. Norway is

has even longer-term potential to keep playing a

also thought to have considerable blue hydrogen

significant role.

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The US Gulf Coast is poised for rapid methane and CCS development

The US Gulf Coast could establish global leadership in the low-carbon energy transition, given its vast energy infrastructure, concentrated emissions hubs and offshore CO2 storage potential

t seems that every week there are more announcements of corporate pledges to achieve low carbon

goals by some future date (say 2030). These kinds of announcements have extended beyond the typical oil and gas and petrochemical sectors and

DR. TIP MECKEL

DR. ALEX BUMP

DR. SUSAN HOVORKA

Gulf Coast Carbon Center, Bureau of Economic Geology, University of Texas at Austin

now include just about every major business and industry sector in the global economy (now upwards of 20% of the largest global companies), including shipping, aviation, IT (think low-carbon cloud storage), LNG, steel, cement, apparel, agriculture, and many others.

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Regardless of how rapidly reliance on fossil fuels may be reduced globally, tools for reducing ongoing emissions are needed, including possibly even direct removal from the atmosphere (DAC). In the US, the shale gas revolution has created new export opportunities for LNG, when a decade ago those facilities were designed for import. So, if there is a defined need to reduce emissions from these existing and future sources, the question then becomes: how? It is generally agreed by those who think deeply about the topic that few of the low-carbon goals can be met efficiently and, more importantly, cost effectively, without carbon capture and storage (CCS). While there are indeed many ways to make gains in emissions reductions (efficiency, renewables, naturebased solutions, reuse, etc.) there is arguably no single more effective hammer in the emissions reduction toolbox than CCS, and one that is able to address hard-to-otherwise-abate sectors. Furthermore, it seems there may be no more concrete way to defend ESG or corporate low-carbon statements than by permanently storing CO2 emissions underground that would otherwise have gone into the atmosphere. Stored CO2 can be credibly documented through wellhead metering and effective monitoring and regulatory compliance. The rapid development of offshore CCS projects around the North Sea (Northern Lights in Norway, Porthos and Athos projects in Rotterdam, Teesside-Humber and Acorn in the UK) seems to provide some insight into the growing realisation that offshore CCS can provide for, and indeed is likely to outperform, our collective goals for reducing emissions using the technology. Recent announcements of offshore acreage leases for CCS in Texas and the MoU between the Port of Corpus Christi and the Texas General Land Office reinforces this trend. China has now announced a first offshore CCS project, as has Indonesia, and Brazil (Lula) and Australia (Gorgon) have been active in offshore CCS for years. It is generally apparent now that the offshore basins that were the primary sources of hydrocarbon production will become the workhorses of the nascent CCS industry as well, leading to untold opportunities to re-commission infrastructure and create additional value. My co-authors and I at the Gulf Coast Carbon Center recently outlined the roadmap for the concept of regional CCS hub development for the Gulf Coast of the US in an openaccess article in the journal of Greenhouse Gases Science and Technology, entitled Carbon capture, utilisation, and storage

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hub development on the Gulf Coast. That article highlights the existing vast energy infrastructure, concentrated emissions

Map of the north-western Gulf Coast (TX, LA, MS – see inset map, lower left) illustrating the extremely favourable setting for further developing CCUS hubs in the Gulf Coast.

hubs, and tremendous offshore deep subsurface geologic storage potential in the Gulf of Mexico (see Figure 1). In short, the Gulf of Mexico can be the end game for abatement of

The development of CCS will not only facilitate

CO2 emissions from a host of crucial energy chains in the US.

decarbonisation of key energy chains, but can also provide job

Infrastructure includes existing CO2 and hydrogen pipelines,

retention and growth, and increase competitiveness in the rapid

petrochemical handling facilities, available depleted oilfields

‘greening’ of global energy economy. And blue hydrogen seems

for CO2 enhanced oil recovery, and vigorous development of

to be having its moment in the headlines as well (recall CH4

LNG exports.

-> H2 + CO2). The consulting firm McKinsey estimates that the

There are now multiple examples of successful integrated

market for carbon credits could be worth upward of $50bn in

CO2 capture, transport, and subsurface injection in the Gulf

2030. It is hard to identify other energy markets that could rival

Coast, such that CCS is quickly moving from demonstration

the growth that is expected in low carbon solutions including

to full commerciality. CCS has been under development for

CCS in the next ten years.

more than 20 years, which is a typical evolutionary path

Globally, CO2 is likely to move to the areas where it is

for new technology to reach widespread commerciality.

most cost effective to conduct giga-ton scale storage where

It is demonstrably proven safe and reliable as currently

economies of scale can be realized – the basins adjacent to

deployed. Handling of CO2 (transport) is already routine in

industrial ports on continental margins. This point is elaborated

many industrialised areas. Subsurface geological storage is

on in another 2019 open-access journal article in Nature

undertaken in subsurface geology using the same principles,

Scientific Reports by myself and Dr. Phil Ringrose of Equinor.

engineering, and fluid physics as those settings that have

In that paper it is estimated that to achieve global emissions

retained hydrocarbons for millions of years. Thus, the

reduction goals by 2050, essentially four to five marine basins

primary barriers are not technical but rather related to

globally need to deploy CCS through offshore injection at

policy and economics.

rates of development consistent with the number of wells

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drilled for hydrocarbon extraction in the Norwegian North Sea since exploration began. Suffice it to say that CCS is likely to

patents related to CO2 are in development by multiple entities. To summarise: CCS is more mature than many realise – all

be a regional growth industry that rivals the scale of historic

the component technologies are currently available (and many

hydrocarbon extraction, which makes sense since we are

are in development), it is demonstrably safe and effective (as

essentially reintroducing the unwanted parts of hydrocarbons

demonstrated through extensive regulatory monitoring) and

(CO2) back into the same regions they were extracted from.

the financial feasibility is attractive, especially in the US where

Many see an element of poetry to that.

Section 45Q tax credits lead to baseline $500mn project tax

Most are unaware of the sleeping giant in the global low-

credit value for a 1 mm metric tonne/year injection for 12

carbon energy transition: shipping. Multiple companies in

years (notwithstanding the potential near-term enhancements

several countries are actively developing low carbon solutions

currently under consideration). If a company’s business thesis

for shipping. It will soon be possible to transport low-carbon

is that the global demand for methane and (blue) hydrogen

fuels (possibly earning a price premium) and energy (LPG, LNG)

is likely to grow in coming decades to address various low-

and energy carriers (ammonia and hydrogen) by ship, power

carbon energy needs, then CCS is an imperative. The good

those ships with low-carbon fuels or otherwise capture the

news is that it can be profitable in the right place (favourable

emissions from vessel power, and also transport liquefied CO2

geology adjacent to concentrated emissions hubs, as in the Gulf

(LCO2) such that vessel deadheading will be eliminated. The

Coast, etc.). Implementing CCS will drive growth and increase

Norwegian Northern Lights project intends to use vessels to

competitiveness in a global market increasingly demanding low

transport CO2 from emitters to offshore storage. Other marine

carbon energy, especially related to methane development.

A $100bn Gulf CCS hub U S major ExxonMobil floated the idea in April of a

and the surrounding area, potentially capturing all CO2

$100bn project that could eventually capture up

emissions from the petrochemical, manufacturing and

to 100mn metric tons/year of CO2 from industry in the

power generation facilities there. The CO2 would then be

Houston area and sequester it beneath the Gulf of Mexico.

transported offshore via pipeline for storage.

The US Department of Energy estimates that geological formations along the Gulf coast could sequester as much

support of industry and government, with a combined

as 500bn mt of CO2 – equivalent to more than 130 years

estimated investment of $100bn or more,” Blommaert

of total US industrial and power generation emissions

explained. “But the benefits could be equally big: early

based on the level in 2018.

projections indicate that if the appropriate policies were

“Houston has two features that make it an ideal site

in place, infrastructure could be built in Houston to safely

for CCS: it has many large industrial emission sources, and

capture and permanently store about 50mn mt of CO2

it’s located near geologic formations in the Gulf of Mexico

annually by 2030. By 2040, it could be 100mn mt.”

that could store large amounts of CO2 safely, securely and

Lessons learned from the project could eventually be

permanently,” Joe Blommaert, president of ExxonMobil

applied to other areas of the US where industrial activity

Low Carbon Solutions, wrote on April 19 in a blog post.

is similarly concentrated near to potential sequestration

According to Blommaert, the US could establish a “CCS Innovation Zone” along the Houston Ship Channel

“It would be a huge project, requiring the collective

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sites, he said, such as in the Midwest or at other locations along the Gulf Coast.

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Making CCUS pay:

The US perspective 40

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The US has increased incentives for carbon capture utilisation and storage (CCUS) technologies in recent years, though further improvements are needed to achieve economywide commercialisation JOSEPH MURPHY

eaching net-zero emissions by 2050

“What remains is primarily a policy challenge

simply cannot be achieved with significant

rather than a technical one,” Jessie Stolark, public

advances in carbon capture utilisation and

policy and member relations manager at the Carbon

storage (CCUS) deployment, as the International

Capture Coalition (CCC), tells Global Voice of Gas

Energy Agency and many other respected energy and

(GVG). “Carbon capture requires the same level of

climate forecasters have concluded.

federal and state policy support currently enjoyed by

The scale of this task is daunting, however.

other low and zero-carbon technologies such as wind

What will need to emerge is an industry worth

and solar, if we are to scale up deployment, which

many trillions of dollars, similar in value to the

will in turn spur innovation and bring down costs.”

oil and gas industry today, in order for climate

This positive cycle of private investment

targets to be reached. There is an urgent need for

in deployment, leading to innovation and cost

largescale investment to flow into this industry,

reductions, followed by greater investment and

which though widely considered technologically

deployment, has already played out in recent years

ready for the challenge, is still only at a nascent

with wind and solar energy, she says.

stage of development. Governments are debating ways of stimulating this development, and it is worth looking at what incentives they could provide to achieve this end.

“We now need the same level of policy support for carbon management to flourish.” In the US, the primary mechanism for spurring the development of the carbon management sector has been the incentive-based 45Q tax credit. This

The US landscape

tax credit is provided to carbon capture, direct

The US has more than half a century of experience

air capture, and carbon utilisation projects that

capturing and storing commercial volumes of CO2,

demonstrate either secure geological storage or

with 12 sites in operation across the country with

beneficial use of the captured CO2 or its precursor

a combined capacity of 25mn metric tons/year.

carbon monoxide (CO) as a feedstock to produce

These sites are serviced by more than 8,000 km of

fuels, chemicals, and products that result in a net

CO2 pipelines.

reduction in emissions.

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“ What remains is primarily a policy challenge rather than a technical one” — Jessie Stolark, Public policy and member relations manager, Carbon Capture Coalition

The US expanded and reformed the 45Q credit through the bipartisan FUTURE Act in 2018, and additional bipartisan legislation was passed last

needed certainty and business model flexibility, the CCC believes. “Needed policies include both supply and

December to provide significant federal funding

demand-side policies to drive private investment in

for early commercial demonstration of key carbon

commercial technology development,” Stolark says.

management technologies. These changes “provide

“On the supply side, this includes enhancements to

the foundation for commercial-scale deployment of

the 45Q tax credit and complementary measures

carbon capture, removal, transport, utilisation, and

to ensure adequate CO2 transport and storage

storage technologies in the US,” Stolark says. “These

infrastructure. Realising the full market potential

legislative accomplishments have the potential to

for CCUS requires a range of market development

position the US with the most significant financing

measures, including procurement standards and

structure in the world for commercial deployment of

policies as well as additional breakthroughs in

carbon management.”

carbon utilisation technologies and processes enabled by federal R&D.”

The work ahead However, more legislative improvements are needed. “Enabling truly economywide commercialisation of CCUS technologies and

project development, the CCC argues. “The most important next step is providing a

the development and buildout of associated

direct pay option for the federal Section 45Q tax

CO2 transport and storage infrastructure

credit,” Stolark says. “Direct pay would address

requires further improvements to 45Q and a

the current significant loss of tax credit value

complementary portfolio of additional federal

to burdensome, costly and inefficient tax equity

state policies,” Stolark continues. “If enacted,

transactions, creating an urgently needed alternative

key provisions in several bipartisan bills before

for most project developers, who otherwise lack

the 117th Congress, and largely mirrored in the

sufficient taxable income to fully utilise the credits, or

Biden administration’s American Jobs Plan, could

who are exempt from federal tax liability altogether.”

deliver an estimated 13-fold scale-up of carbon

The construction window for the 45Q credit

management capacity and 210-250mn metric tons

should also be extended by ten years until the end

in annual emissions reductions by 2035.”

of 2035, according to the coalition, establishing “a

Adopting a full suite of supportive policies would bring down project costs and give investors the

The US needs to close the gap between the current value of the 45Q tax credit and the cost of

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critically needed investment horizon to give carbon management projects the time required to scale

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up between now and mid-century. Increased credit values are needed to drive deployment, particularly in sectors that have less pure CO2 emission streams, including certain industrial sectors, electric power generation and direct air capture.” The CCC also considers the current eligibility thresholds in the 45Q programme as arbitrary. “They serve no policy purpose and reduce

CCUS Goes Global A

nother hotspot for CCUS is the North Sea, with Denmark, the

Netherlands, Norway and the UK all placing the technology at the heart of their

the overall technology innovation and emissions

decarbonisation plans. One such project

reduction potential of the incentive – currently,

is Northern Lights, led by Norwegian state

approximately 54% of power plants and 75% of

company Equinor, which aims to store

industrial facilities fall below eligibility thresholds,”

5mn metric tons/year or more of CO2

Stolark says.

from industries in Norway and elsewhere

Annual capture thresholds should also be

in Europe under the North Sea bed (see

eliminated, and robust infrastructure is needed to

“Europe makes strides in CCS” in Global

transport and store captured CO2.

Voice of Gas Issue 2 for more details).

“The most important next step here is enactment

Norway is also the location of the largest

of the bipartisan Storing CO2 and Lowering Emissions

existing CCS facilities in Europe, at the

(SCALE) Act, which would enable deployment of

Sleipner and Snohvit fields.

the essential backbone CO2 transport and storage

There have been a flurry of CCUS

infrastructure needed to achieve net-zero emissions

developments recently elsewhere in the

by mid-century,” she says.

world.

The oil and gas industry has a key role to play in

In July, for example, China’s Sinopec

CCUS development, not only due to its emissions but

started work on what will be the country’s

also because of the workforce it can bring to bear.

first large-scale CCUS project. It will

This workforce is “uniquely poised to commercialise

capture CO2 emissions that result from

carbon capture, including oilfield services, geoscience professionals, engineers and other experts that will be key to economywide deployment of carbon capture,” Stolark says. CCUS is essential for meeting the world’s

hydrogen production at Sinopec’s Qilu refinery in the east Shandong province. The CO2 will then be injected into wells at the Shengli oilfield, in order to boost recovery. In August, Indonesia’s upstream

ambitious targets on emissions reductions, the CCC

regulator SKKMigas approved a plan to

believes, and its deployment will also help safeguard

store up to 25mn mt of CO2 at the offshore

and create US jobs across various industries. “We must rapidly decarbonise existing fossil

Vorwata field, while Australian energy consultancy Codus won a contract to

energy production and use, even as we aggressively

design a CCS project in Malaysia. In South

scale up alternatives,” Stolark concludes. “Excluding

Africa that same month, authorities invited

the full portfolio of carbon management technologies

quotes for geological surveys for that

from our climate toolkit will not only result in

country’s first CCUS initiative.

significant increases in the cost of achieving overall

And these are only some of the examples.

emissions reductions, but it will also pose an unacceptable risk of failure to meet climate goals.”

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Complementary colours:

developing blue and green hydrogen trade H Different types of hydrogen

ydrogen is increasingly at

have different target users,

on how countries and

the forefront of the debate

but blue hydrogen has the

industries can decarbonise and hit long-

potential to ease the way

gas (GHG) emissions. And indeed, the

for green hydrogen

term targets of net zero greenhouse number of early-stage projects being unveiled is rising rapidly as various players try to put ideas about using

ANNA KACHKOVA

G L O B A L VO I C E O F G A S

hydrogen into practice.

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There are various obstacles to navigate if a global

reformers and CCS technology cost-effective, whereas

hydrogen economy is to be developed, however.

a green hydrogen project can start small with a single

These include the costs involved in both production

electrolyser and build up from there.

of the cleanest – and generally most expensive –

This is one of the major challenges relating to

forms of hydrogen and the infrastructure required to

blue hydrogen, according to Ganbold, and one that

trade it internationally.

has also been flagged up by others. David Maunder

Additionally, countries will have to address

and Zeynep Kurban at professional services firm GHD

questions over which form of hydrogen to target, either

also identify economics and scale as being two key

as an exporter or an importer. Some are well-placed

elements in the discussion over blue versus green

to enter the nascent market for green hydrogen, which

hydrogen.

is produced via electrolysis, using renewable energy.

Another challenge is the fact that the combination

Others, meanwhile, are better positioned to embrace

of CCS with steam reformation is still in its early

blue hydrogen, which is produced from natural gas,

days, resulting in many uncertainties relating to

with carbon capture and storage (CCS) used to address

feasibility and cost.

the emissions arising from the process. Those advocating for a more rapid energy transition and a full exit from fossil fuels believe that blue hydrogen should be bypassed in the pursuit of green hydrogen. However, given the current costs of green hydrogen from many sources, this is not

“The efficacy of the blue hydrogen ‘system’ depends fundamentally on the development and delivery of CCS infrastructure,” Maunder and Kurban tell GVG. A third challenge for Ganbold is the location and purity requirements of end-users. “If you are producing blue hydrogen at scale, you

economically feasible. And indeed, there is potential

are not necessarily close to your offtakers, which

for the more widespread adoption of blue hydrogen

means you have to factor in the costs of conversion

to boost overall demand, ultimately encouraging the

and transport,” Ganbold says. “Steam reformation

growth of green hydrogen as more players look at

also results in a less-pure form of hydrogen

different options for participating in a growing market.

compared to electrolysers. For this to be used in fuel cells, it will need a further purification step, which

Finding a fit Blue and green hydrogen have different target users

Nonetheless, she believes that blue hydrogen has

and benefits, notes Anise Ganbold, global energy

many advantages, including lower overall costs versus

markets lead at analytics firm Aurora Energy Research.

the green variety, as well as the fact that it provides a

The question of how blue and green hydrogen can

market for natural gas.

best complement each other is therefore dependent on country-specific circumstances. “Blue is advantageous for a country with a large

Maunder and Kurban, meanwhile, note the challenges involved in reducing the overall GHG emissions that come from the production of blue

domestic source of natural gas and easy access to

hydrogen, particularly with regard to fugitive methane

CCS sites such as Britain and Norway,” Ganbold

emissions associated with the natural gas used as

tells Global Voice of Gas (GVG). “In contrast, green

feedstock for the process.

is excellent for a country with strong renewable

“For blue hydrogen to be considered part

generation potential such as Spain, and a country

of an effective transition to net zero, this issue

that is large with isolated communities that could

needs to be more rapidly addressed with industry

decarbonise with electrolysers, such as Australia.”

acting faster on implementing abatement options,

However, scale is necessary in blue hydrogen development to make investing in both steam

also adds to costs.”

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coupled with strengthening policy and regulatory frameworks,” they say.

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There is potential for the more widespread adoption of blue hydrogen to boost overall demand, ultimately encouraging the growth of green hydrogen as more players look at different options for participating in a growing market.

different ways of developing hydrogen. The more players are involved in testing hydrogen technologies and developing scale, the more costs will go down. “In some parts of the world, particularly in places where the cost of blue hydrogen is currently significantly lower than that of green hydrogen, largescale blue hydrogen production is seen by many as being an important element in the stimulation of demand at scale, so creating the ‘pull-through’ for green hydrogen production,” say Maunder and Kurban.

Forging ahead Various countries are now emerging as future buyers and sellers of both blue and green hydrogen.

Logistics

exporters, but the first movers are looking to be the

plans, in addition to considering how to produce

UAE and Australia shipping clean ammonia to Japan,”

cleaner hydrogen in an economic manner, they

says Ganbold, adding that Russia is also targeting

will have to address questions of logistics and

hydrogen exports to Europe and Asia.

infrastructure. Currently, various companies are

GHD also sees Australia as having the potential to

experimenting with the introduction of hydrogen

be a leading exporter of hydrogen. Maunder and Kurban

blends into existing gas pipeline networks, though

also cite “great potential” for export-led opportunities in

GHD notes that this comes with its own challenges.

the Middle East and North Africa, as well as mentioning

“There are limits to the level of hydrogen that can be accepted into most existing natural gas systems,

Chile and its green hydrogen export ambitions. “Importers could be anywhere in the world in

both due to the suitability of the existing infrastructure

which the demand-side of the trade picture has

for safe transmission of hydrogen and due to the design

emerged and is moving to maturity,” they add. “This

and operation of end-use appliances and technologies,”

includes countries such as Japan and a number of

say Maunder and Kurban. In addition, the overall GHG

countries in Europe.”

benefit of blends is relatively small, they say. “However, the main benefit of using hydrogen

Maunder and Kurban anticipate that the development of the hydrogen economy will initially

as a blend in existing natural gas systems is that it

be driven by regional markets, but that once demand

could enable the potentially rapid emergence of

has emerged and has begun to mature, global trade

a hydrogen market, with substantial demand that

could pick up relatively fast. This is because of the

could significantly drive down the cost of green

emergence of countries with the potential for low-cost

hydrogen production through electrolyser technology

hydrogen production at scale.

improvement and high-volume manufacture,” Maunder and Kurban add. Indeed, if the other challenges relating to blue

“At Aurora we’ve tracked multiple potential

As hydrogen developers move forward with their

In Ganbold’s view, domestic and international markets have the potential to grow at the same time. “If a country abroad can produce clean hydrogen

hydrogen can be overcome, its potential to spur the

cheaply, having a low-cost source will encourage

broader development of a hydrogen economy has

hydrogen demand growth domestically,” she says.

positive implications for green hydrogen too. Growing

“Demand for clean hydrogen will be essential to grow

supply is anticipated to stimulate demand, which in

a hydrogen economy, and getting the cost of supply

turn will encourage more producers to look at the

down is key for that.”

G L O B A L VO I C E O F G A S

O C TO B E R 2 0 2 1

Methane pyrolysis:

a potential gamechanger? While most of the focus has been on steam methane reforming and electrolysis, methane pyrolysis is another option for producing lowcarbon hydrogen that has garnered much less attention

any countries have turned to hydrogen as a means of decarbonising areas of their economy that would be difficult to abate

otherwise. But while there are several low-carbon ways of producing the fuel, two methods have commanded most of the attention. The first is to use electrolysers, powered with renewable energy, to separate water into so-called green hydrogen and oxygen. The second, currently a significantly cheaper option, is to use steam methane reforming (SMR) and carbon capture to produce blue hydrogen from natural gas, capturing and

JOSEPH MURPHY

G L O B A L VO I C E O F G A S

safely storing the resulting emissions.

O C TO B E R 2 0 2 1

Hydrogen production costs 100%

Water electrolysis Steam reforming

Production costs

75%

Methane Pyrolysis

50%

25%

100

1,000

10,000

100,000

Capacity of H2 production plants, m3/h Source: New Process for Clean Hydrogen, Dr. Andread Bode. BASF Press Research Press Conference 10.01.2019

However, there are those that advocate for a third option, known as methane pyrolysis. This new process involves splitting natural gas through thermal

water use at all. “It can also be developed at much smaller scales

decomposition in the absence of oxygen, into what

than blue hydrogen,” Christopher Brandon, co-

is known as turquoise hydrogen and solid carbon.

founder and director at EH, tells Global Voice of Gas

Pyrolysis technologies have been around since the

(GVG). “Blue hydrogen is inherently for large scale

1950s, although proponents view it as a potential

applications only.”

gamechanger. According to Switzerland-based EH Group

Stefan Petters, the founder of a non-profit organisation from Austria called Carbotopia, notes

Engineering, which is developing a process of

that turquoise hydrogen can be undertaken at the

microwave pyrolysis based on research at the

point of energy use, rather than at larger, central

University of Oxford, a key advantage of pyrolysis is

hub, as is the case with blue hydrogen. Carbotopia

that it can be highly energy efficient. It uses only 10-

has developed a thermocatalytic methane

20% of the energy required for electrolysis and less

dissociation technology to derive hydrogen and solid

than a half required for SMR, the company estimates.

carbon from natural gas.

Another advantage is that it can leverage existing

quantities of water, pyrolysis does not involve any

Brandon also points to some technical

gas infrastructure already in place, like SMR, but

complexities of capture and storage for CO2

without requiring additional infrastructure for

emissions from blue hydrogen production. He notes

carbon capture utilisation and storage (CCUS). And

that pyrolysis can have a zero carbon intensity,

while both SMR and electrolysis require significant

provided that it is powered using renewable energy,

G L O B A L VO I C E O F G A S

O C TO B E R 2 0 2 1

whereas SMR still emits some CO2 due to limits to

and storage underground, as producers do this to

how much can be captured.

boost oil recovery at their fields. Operators would

“At the moment it’s just not technologically possible to capture all the CO2,” he says. And whereas CO2 in most cases will have to be stored, pyrolysis results in carbon products that are valuable in industry, such as carbon black,

rather stick with what they do already, in this case SMR, and add CCS to make the process cleaner, rather than invest in new assets to undertake pyrolysis, Petters adds. Brandon also concedes that it will be tough to

needle coke, graphite and carbon nanotubes. Were

convince some of the climate benefits of turquoise

pyrolysis to be developed at scale, the output

hydrogen, as there is resistance in some quarters of

of carbon products would dwarf the market for

society to deriving any clean fuel from hydrocarbons.

them, and so the majority would still have to be

There has also been pushback against blue hydrogen

sequestered, Brandon says, although this would be

for this reason.

a more manageable task than dealing with carbon

“We think that pyrolysis will get tarnished with

emissions. Solid carbon is easier both to transport

the same brush,” Brandon says, noting that gas

and to store.

producers should focus on eliminating their methane

Meanwhile green hydrogen can only be produced where there is an abundance of cheap renewable electricity.

emissions to strength the case for gas-derived hydrogen. “Scalability is extremely high,” Brandon says. “But

“Obviously there’s a massive push towards green

it just needs to overcome the technical challenges

hydrogen, but there’s some areas of the world, such

first. We’re still at too low a technology readiness

as Russia, where pyrolysis likely makes more sense,”

level on these approaches, and I don’t see that

Brandon says. “You don’t have the really cheap

changing for the next couple of years.”

renewables there, so producing green hydrogen

Brandon calls for increased government support

would be very expensive. But there is an abundance

for pyrolysis to get past these technological hurdles.

of natural gas.”

There are only around a dozen groups working on

Brandon and other advocates believe that with

pyrolysis methods right now, he says. Besides EH,

development over time, pyrolysis can produce

include Hazer Group in Australia, Gazprom in Russia,

cheaper hydrogen than either SMR or electrolysis

BASF and the Karlsruhe Institute of Technology, and

(see Figure 1). Exactly how cheap depends on the

Monolith and C-Zero in the US.

price of natural gas, as well as how valuable the solid carbon by-products are.

“This seems a very small number to be working on a technology that could be a really useful bridge between what is happening now and where we need

The hurdles

to get to in terms of emissions,” Brandon says. “Some

So why has turquoise hydrogen not taken off?

R&D support would be welcome.”

“There are still big technological hurdles with

and its important as a potential means of reducing

“None of the methods have been able to generate

emissions. Meanwhile Petters is bullish on the long-

enough pure hydrogen and effectively separate the

term outlook for turquoise hydrogen, believing it will

solid carbon.”

become the “global standard” for hydrogen and will

In contrast, SMR is already well established in the oil and gas industry, he says, as is the CO2 injection

Still, Brandon is confident of pyrolysis’ scalability,

all the approaches of pyrolysis,” Brandon says.

G L O B A L VO I C E O F G A S

be produced in greater quantities than blue hydrogen within ten years.

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The major decarbonisation prize of biomethane de-mystified To initiate the process of scaling up renewable gas production and consumption, policy will play a critical role

MARTIN LAMBERT

TATIANA KHANBERG,

Senior Research Fellow,

Senior Public Affairs Manager,

Oxford Institute for Energy Studies

International Gas Union

G L O B A L VO I C E O F G A S

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e are standing at the threshold of a major global climate milestone set to take place in Glasgow next month,

where the 137 countries that signed the Paris Agreement six years ago, will attempt to negotiate a way forward to reaching its goals at COP26. Taking national commitments under the COP process from pledge to reality will require both exceptionally rapid and massive structural change in the entire global energy system, including the gas industry. Natural gas supply would also need to find ways to progressively decarbonise. This would be

sourced gas and to use existing infrastructure and

achieved by applying low, zero, and negative carbon

equipment to transport and use it. For example,

technologies – such as carbon capture, hydrogen,

in Europe only around 10% of biogas is upgraded

and biogas/biomethane.

to biomethane, and the rest is consumed in small

The interest in renewable gas and hydrogen has been growing, and it has increasingly been making entry into a plethora of energy transition strategies.

volumes on site; and outside of Europe, the upgrading capacity is quite small3. At the same time, the total sustainable biogas

However, to turn this interest into action, concrete

production potential is estimated by the IEA to be

measures will be required from the industry,

over 20 times the current level4. If this potential level

governments, and financial and civil society actors

were to be reached for grid quality biomethane –

alike. Many articles focus on hydrogen, but we think

it could offset around 20% of today’s natural gas

it important that biogas and biomethane also receive

demand – and have an enormous decarbonisation

sufficient attention.

benefit. However, that also requires a very rapid

Let’s consider the numbers.

build-up of biomethane production capacity. It is

Natural gas provided around 25% of total

important to stress that this production level is

global primary energy in 2020, according to the BP

considered sustainable, largely from waste streams,

Statistical Review . That represented total global

including forest residues used for gasification. This

gas demand of 3.850 trillion m3, equivalent to

level of production would not compete with food for

around 40,000 TWh (in 2020), while the total global

agricultural land.

production of biogas and biomethane (in 2018) was

It may also be helpful to de-mystify the process

estimated around 400 TWh (35 Mtoe) , or just 1%

behind biomethane technology. It generally begins

of the size of total natural gas production. A little

with making biogas through anaerobic digestion of

over half of that production is concentrated in a few

waste using enzymes to convert a wide range of

countries in Europe, with a further 25% in China.

organic material. The output is a combination of

An even smaller portion of this volume is

methane and CO2, ranging from 40% to 60% methane

upgraded to biomethane – the process that purifies

content depending on the feedstock and process.

biogas to make it fully interchangeable with fossil-

The resulting biogas can be used to produce heat

1 BP Statistical Review (2021): https://www.bp.com/en/global/corporate/energy-economics/statistical-review-of-world-energy.html 2 IEA Outlook for biogas and biomethane (2020): https://www.iea.org/reports/outlook-for-biogas-and-biomethane-prospects-for-organic-growth 3 European Biogas Association (2021) https://www.europeanbiogas.eu/eba-annual-report-2020/ 4 IEA Outlook for biogas and biomethane (2020)

G L O B A L VO I C E O F G A S

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Industry too must do its share and continue to push the envelope on technology innovation and deployment opportunities.

To initiate the process of scaling up renewable gas production and consumption, policy will play a critical role. Similar policy measures to those for renewable power have been proposed to drive adoption, including low-carbon fuel standards, renewable portfolio standards, and production incentives. So far, such policies have been most widespread and effective in scaling up markets within Europe. In Denmark for example, the use of feed-in-tariffs has enabled renewable gas production to scale up to 10% of the national gas supply, a share that is projected to grow to 30% by 2030, with a target for the gas grid to be 100%

and power on site, or upgraded to biomethane to be

biomethane by 2040. Meanwhile, France recently

integrated into natural gas infrastructure, once CO2

launched a comprehensive programme to provide

and other contaminants are removed. When biogas is

purchase price stability for the next decade, thereby

upgraded to biomethane with a concentration of 98%

incentivising capital investment in renewable gas

or more methane content, it can be integrated into

production. These are just a few examples of

existing gas pipelines and used in existing equipment.

supportive policy measures that could unlock major

Biomethane can also be made from dry biomass

decarbonisation opportunities.

(typically wood chips or municipal solid waste) by

push the envelope on technology innovation and

relatively early stage of development.

deployment opportunities.

At present, most biogas is consumed near its

The scale of the global energy transition challenge

source of production, either for power generation

is simply too large for any one lever to solve it. This is

or in combined heat and power applications, but

a multifaceted communal task, requiring collaborative

to reach the required scale for decarbonisation,

solutions from the industry, governments, the

biomethane capabilities need to be ramped up at a

financial community, and civil society.

great pace. There are six different process technologies are

Industry too must do its share and continue to

thermal gasification, but this technology is still at a

As a quarter of the world’s energy demand is today met by gaseous fuels, at present

available for biomethane conversion, yet all have

predominantly natural gas, it is clear that the

only been deployed in limited capacity, thus there is

gaseous component of the world’s energy system

significant potential for scale and learning effects to

is foundational, and for any realistic rapid energy

lower the costs of the process. In a recent analysis

transition to occur, the gas network will continue

by IGU and BCG, the future cost projections for

to play a critical role. It is also clear that current

gas technologies estimate that scale and learning

production of renewable gases (biogas, biomethane

effects could reduce the capital costs of biomethane

and low-carbon hydrogen) is very small in that

production by 45% to 65%, and operational costs

context. This underlines the scale of the challenge

by 10% to 20%, by 2050. Yet even if cost reductions

in ramping up production significantly in the coming

are relatively small, renewable gas can provide

years. It is also noteworthy that total renewables

a more cost-effective means of reducing GHG

contribution to primary energy currently is only 6%,

emissions in buildings and industry applications than

so the scale up challenge applies to all forms of

electrification in many cases.

renewable energy and not just renewable gases.

G L O B A L VO I C E O F G A S

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Greening our gas grids:

Should we leave for tomorrow what we can do today? If we look at the available resources, biomethane is today the only renewable gas available at commercial scale and the most cost-effective

G L O B A L VO I C E O F G A S

ANGELA SAINZ ARNAU Communications manager, the European Biogas Association

O C TO B E R 2 0 2 1

he European Commission released

Existing gas infrastructure, needs to be adapted

this summer the long-awaited ‘Fit for

and further developed for the transmission

55’package under the European Green Deal.

and distribution of hydrogen. This will mean

The package is aimed at putting the EU on track for a

additional investments on the current gas grid

55% reduction in carbon emissions by 2030, and net-

during the coming years. Biomethane conversely is

zero emissions by 2050. To make Europe the world’s

indistinguishable from natural gas, but it is derived

first climate neutral continent, renewable power and

from biological materials rather than from fossil fuel

gas must become the main sources of energy for

deposits. This means that it can be used without

the entire economy. Electricity, which is now mostly

the need for any changes in transmission and

produced from fossil fuels, will need to decarbonise,

distribution infrastructure or end-user equipment,

and so will our gas grids.

and is fully compatible for use in natural gas vehicles. Biomethane can deliver the energy system

Biomethane is Fit for 55

benefits of natural gas while being carbon-neutral or

If we look at the available resources, biomethane

even carbon negative.

is today the only renewable gas available at

The decarbonisation of the gas grid is

commercial scale and the most cost-effective. On top

urgent and we should not wait for the maturity

of that it can achieve even negative carbon emissions

of new technologies or the adaptation of the

which is unique. On the green hydrogen side there

infrastructure when we already have solutions

are multiple ongoing projects and this renewable

at hand. 2020 will be the year with the largest

alternative will play an important role in the future

amount of new biomethane plants in Europe to

energy mix. However, these technologies are not yet

date, according to the data collected for the

fully commercial today for large-scale production.

upcoming Statistical Report of the EBA, which will

G L O B A L VO I C E O F G A S

O C TO B E R 2 0 2 1

be released next November. The industry is now

long distances, but this increases their volume

producing the energy equivalent larger than the

and weight and therefore that of vehicles, to the

total consumption of Belgium, according to various

detriment of their efficiency and their environmental

studies, and in 2050 this may represent up to 30-

footprint. To operate a 40-tonne HD truck for

40% of total gas consumption in Europe.

over 1,000 km, an electric truck would require a

Biomethane is already contributing to abate

6.4-metric ton battery with today’s best technology,

both carbon and methane emissions. Its production

while the same distance can be covered easily

prevents emissions across the whole value chain,

with a compact safe storage of bio-LNG. There are

with a three-fold emissions mitigation effect.

also important factors to consider before putting

Firstly, avoiding emissions that would otherwise

excessive pressure on the battery manufacturing

occur naturally: organic residues are taken to the

process. The world reserves of raw materials such

controlled environment of biogas plants, preventing

as cobalt and lithium concentrate in geographic

the emissions produced by the decomposition of

areas with weak environmental regulations and

the organic matter from being released into the

compliance with human rights.

atmosphere. Secondly, the biomethane produced

If we look at maritime transport, this sector

displaces fossil fuels as energy source. Thirdly, the

carries 80% of the world’s goods, but less than 1%

use of the digestate obtained in the production

of the world fleet runs on alternative fuels today.

process as biofertiliser helps return organic carbon

The ‘Fit for 55’ package foresees an increase of

back into the soil and reduces demand for the

bio-LNG in maritime energy of 14.2-16.8 % by 2050,

carbon-intensive production of mineral fertilisers

depending on the type of political incentives. LNG

whilst improving the soil.

is considered as a transitional fuel paving the way to the use of bioLNG.

Heavy-duty vehicles are going green The deployment of renewable gases is essential

Decarbonising industrial energy demand

to accelerate the reduction of GHG emissions in

Besides its applications in the transport sector,

multiple sectors, including buildings, heat-intensive

biomethane will be the only renewable gas

industries and transport. If we look at the transport

available for those industries who cannot

sector, biomethane in its liquefied form (bio-LNG)

be connected to hydrogen grids. Biomethane

is very well suited to cover demand for heavy-duty

production allows energy-intensive industries to

and maritime transport. CNG and LNG vehicles, such

cut energy costs and replace fossil fuels. Besides,

as ships or trucks, are more efficient in terms of GHG

energy production from industrial waste streams

emissions savings than those fuelled by oil or diesel.

that cannot be re-used or recycled and have no

Besides, CNG and LNG infrastructure is also suitable

other applications is well in line with the resource

for biomethane and will facilitate its deployment in

efficiency efforts promoted by the EU.

the coming years. Such decarbonisation pathway

up two-thirds of global industrial energy demand

of the existing refuelling infrastructure that can

and comes mostly from fossil-fuel combustion. This

accommodate gaseous drop-in biofuels and

demand can be partly covered with biomethane.

renewable low carbon synthetic fuels.

If we take the example of beer production,

These areas of transport are difficult to electrify. Batteries need high autonomy to cover

Among the different energy uses, heat makes

can be ensured, for instance, through the use

G L O B A L VO I C E O F G A S

biomethane can cover almost the whole energy demand for heating the distillation process.

O C TO B E R 2 0 2 1

The deployment of renewable gases is essential to accelerate the reduction of GHG emissions in multiple sectors, including buildings, heat-intensive industries and transport.

A less explored industrial application of

developing the local economy, creating green jobs,

biomethane is the replacement of current fossil

protecting our environment and the wellbeing of our

based raw materials for the chemical industry

citizens. Biomethane is a true enabler of a circular

to produce plastics, solvents, and synthetic fuels.

economy: we can produce biomethane by treating

As all other industries, the chemical industry will

local organic waste and municipal waste water and

need to embrace sustainability and increasingly rely

this renewable gas can be used to fuel both our

on alternative materials in the coming years. This

public transport and private fleets, facilitating the

forward-looking solution is fully aligned with the

access of all to sustainable mobility. EU cities and

principles of an efficient circular economy.

regions should be encouraged to develop integrated circular city concepts and make an optimal use of

Additional biomethane applications

In the countryside, residues from animal

to go green in the buildings sector. The ‘Fit for

farming or biomass from agriculture can be

55’ package has also promised to improve energy

optimised and converted into energy, while

efficiency in the building sector, supporting

digestate can be used as an organic fertiliser. This

vulnerable customers in this energy transition and

creates additional business models in the farming

setting obligations of renovation and energy savings

sector, making it more cost-competitive, and

in the public sector. This could be an incentive for

promotes sustainable farming.

the deployment of biomethane in households and

their resources.

Biomethane is the cheapest option for society

Looking at its important role in society and the

public buildings with no need for adaptation or

substantial positive effects on GHG abatements,

development of the existing network.

biomethane should receive the relevant support

The production of biomethane also has a

from policy-makers and investors to ensure their

positive impact on the development of circular

fast scale-up. The energy transition should rely on

cities. The circular city concept is essential to make

the smartest combination of sustainable technology

sure our municipalities become more sustainable,

solutions, including biogas and biomethane.

G L O B A L VO I C E O F G A S

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Africa disproportionately hit by investors’ reluctance to back oil, gas

G L O B A L VO I C E O F G A S

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African Energy Chamber chairman NJ Ayuk argues that Africa should follow its own path towards lower emissions JOSEPH MURPHY

frica has taken the biggest hit from the slump in global oil and gas investment that followed the market collapse last year, the chairman of the African Energy Chamber, NJ Ayuk, tells Global

Voice of Gas (GVG). Making matters worse, the continent has also been disproportionately affected by investors’ reluctance to back new oil and gas projects amid growing climate concerns, he says. Africa has a lot of frontier exploration, making it particularly vulnerable to cuts in investment, according to Ayuk, who is also the founder and CEO of Centurion Law Group. While COVID-19 has been a factor, Ayuk sees a great threat from investors’ perception that further support for oil and gas in Africa undermines the energy transition. And this in turn will put pressure on the continent’s economy. “We don’t have the economic might to drill a $60mn or $80mn well, or to develop a field for $4bn to build an LNG train,” he said. “We don’t have that kind of funding.” Many of the largest international oil companies (IOCs) are also scaling back exploration. For example BP, which aims to cut its oil and gas production by 40% over the next decade as part of its transition plan, has said it will not explore in countries where it does not already have a presence. Besides fewer funds, this trend will lead to a shortfall in the expertise and technologies that are needed for some projects in Africa, Ayuk warns. “The exploration money has dried up,” the chairman said. “It is going to cripple a lot of Africa’s new upstream projects.” Faced with this slump in investment, many African countries have taken steps to boost their appeal, including introducing new laws. Yet it is still difficult to attract investors, Ayuk says, pointing to disappointing results from recent oil and gas licensing rounds in multiple countries. Ayuk also hails Nigeria’s recent finalising of a new petroleum law, aimed at providing investors with greater incentives particularly with regards to natural gas development. Both chambers of Nigeria’s parliament passed the bill in July, and it was signed into law by Nigerian president Muhammadu Buhari by the end of the year. “The bill is not everything the industry needs. The industry would have preferred a more robust bill with more incentives and more guarantees

G L O B A L VO I C E O F G A S

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“ Were the advice in the net-zero report followed, it would lead to austerity in Africa, in turn creating instability and crisis”

“The analysis is inaccurate. They’re relying on technologies that do not even exist yet,” he says. Ayuk views natural gas as a bridge fuel in the energy transition, and this is a position that the IEA itself held only a few years ago. “Were the advice in the net-zero report followed, it would lead to austerity in Africa, in turn creating instability and crisis,” he warns. Africa only accounts for 2% of the world’s anthropogenic CO2 emissions, he notes, and should therefore be able to pursue a different path towards sustainable development to other regions like Europe. “We cannot have an unjust transition,” he says. Developed countries promised in 2009 to provide at least $100bn annually to developing nations for financing climate initiatives by 2020, under the UN Framework Convention on Climate Change. But the financing that has arrived has fallen far short of this goal. And in any case, many times more is needed to support for Africa’s energy transition, according to Ayuk,

— NJ Ayuk, Chairman African Energy Chamber

It is largely Western investors that are shying away from new oil and gas projects, although there have been setbacks with other financing options as well. Russia held its first African summit in the Black Sea resort of Sochi in October 2019, and the event was hailed as a success at the time. A raft of memoranda were signed between African and Russian companies, but almost two years on, few of

on fast-tracking petroleum developments and approvals,” Ayuk says. “But still the bill gives us a

those deals have led to firm commitments. Ayuk reasoned that Russia had abundant

chance to kickstart exploration in Nigeria once again.

undeveloped oil and gas resources of its own, and

It gives a lot for host communities. It focuses on

was therefore in no rush to pursue opportunities

incentivising frontier exploration and gives incentives

overseas. There are also limits to how much Africa

for developing Nigeria’s 205 trillion ft3 of proven gas.”

can rely on Chinese financiers, he added.

Africa’s path

seeking $1bn in financing to support further work on

The International Energy Agency (IEA) made a stir in

the $2.8bn Ajaokuta-Kaduna-Kano (AKK) gas pipeline

May when it published its net-zero scenario, in which

amid delays with the disbursement of funds promised

it concluded that no further investment in oil and gas

by Chinese lenders. Negotiations with Bank of China

is needed if the world continues on the path towards

and Sinosure to secure $1.8bn of funds continue,

net-zero emissions by 2050. Ayuk describes the

Reuters said. Chinese lenders were originally

report as a “fairy tale” and a “publicity stunt.”

expected to cover the bulk of the project’s cost.

Reuters reported on mid-July that Nigeria was

G L O B A L VO I C E O F G A S

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Nigeria kickstarts decade of gas with new petroleum bill

The government is embarking on a sweeping natural gas development drive, in order to make its energy cleaner, more affordable and more accessible

hile better known as a major oil producer, Nigeria has vast but largely untapped natural gas resources. In its latest statistical energy review, BP estimates the

country’s proven gas reserves alone at 5.5 trillion m3. Nigeria’s

government believes roughly a further 17 trillion m3 could be discovered. Authorities in Abuja are eager to capitalise on this wealth. They want to see Nigeria expand its LNG exports, already set to

JOSEPH MURPHY

reach 30mn metric tons/year in 2024 when the NLNG consortium commissions a seventh train at their liquefaction complex on Bonny Island. But they are also eager to see gas play a greater role in the domestic economy, both to drive economic growth and improve standards of living, and to reduce emissions by displacing more polluting fuels. The government envisages increased gas use in a range of sectors, from vehicle transport and household cooking to power generation and petrochemicals.

G L O B A L VO I C E O F G A S

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“ The rising global demand for cleaner energy sources has offered Nigeria an opportunity to exploit gas resources for the good of the country.”

almost two decades, with delays attributed to political disagreements. But in a major breakthrough, it was finally approved by both houses of Nigeria’s National Assembly on July 16, and then was sent to the president’s office for approval. The key changes in the bill include reduced and streamlined royalty payments, support for frontier exploration, reforms to national oil company NNPC, and improvements in regulation governing the sector. While some industry voices have said that the legislation does not go far enough in improving investment conditions in Nigeria, it has generally been well-received. “With a primary focus on investor certainty and

— Nigerian president Muhammadu Buhari

transparency, as well as the enhancement of the sector’s attractiveness for international investment, the newly passed PIB is expected to position Nigeria as one of Africa’s top energy markets,” the African

For many years, though, Nigeria’s natural gas

signing into law. “By integrating 16 petroleum laws

observers have blamed on inadequate conditions

into one comprehensive and coherent document, that

for investment across the value chain. But this is set

provides a framework to boost oil and gas output,

to change, after Nigerian president Muhammadu

the PIB will accelerate investment and development

Buhari signed into law a new petroleum industry

in a post-COVID-19 landscape.”

bill (PIB) that overhauls nearly every aspect of the

Energy Chamber said in a response to the bill’s

drive has produced lacklustre results, which many

The chamber’s chairman, NJ Ayuk, added that

country’s oil and gas legislation, in a bid to attract

through the bill’s passing, “Nigeria has managed to

more investors. The bill has been in the works for

elevate itself onto the global energy stage.”

G L O B A L VO I C E O F G A S

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“The recently signed PIB not only increases the

the new law supports gas development in several ways.

competitiveness of the Nigerian energy sector, but

It introduces terms for developing gas under production-

through fiscal incentives, market-driven policies,

sharing contracts for the first time, as well as special tax

and unified regulations, the bill has positioned the

breaks for companies investing in gas projects.

country as the premier investment destination for both regional and international investors,” he said. The bill’s signing was also praised by OPEC,

Critical for the government’s domestic gas plans, the law also prioritises gas supply to the domestic market, providing incentives such as a reduced

whose secretary general Mohammed Barkindo

royalty rate of 2.5% for gas that is consumed in-

described it as an historic achievement.

country, versus 5% for gas that is exported.

“With the stroke of a pen, you have inaugurated a

Buhari announced the Decade of Gas initiative

new era for the industry following years of legislative

in March, which essentially aims to gasify Nigeria’s

efforts to strengthen the legal, regulatory, fiscal and

economy by 2030. The country already relies on gas

governance framework of the petroleum sector,”

for 80% of power generation, but it is also the largest

Barkindo said. “Indeed, the new law will enhance the

user of oil-fired back-up generators in Africa, and a

Nigerian petroleum industry’s reputation, open the door

significant user of coal. Expanding gas use will be key

to new investment and ultimately strengthen its position

for reducing power-sector emissions and increasing

to meet the world’s growing demand for energy.”

electricity access in the years to come.

By helping to expand Nigerian oil and gas

“The rising global demand for cleaner energy

production, he said, the new legislation supports

sources has offered Nigeria an opportunity to exploit

efforts to alleviate energy poverty, in line with

gas resources for the good of the country,” Buhari

the UN’s seventh Sustainable Development Goal,

said when announcing the plan. “We intend to seize

which calls for “affordable, reliable, sustainable and

this opportunity. We are a gas nation with a little oil,

modern energy for all” by 2030.

and we must focus on this gas.”

After the bill cleared parliament, Wood Mackenzie commented that its approval would mean “the fiscal uncertainty deterring investment across the upstream, gas, midstream and downstream will be alleviated.” The bill “offers incentives and concessions made to

The Decade of Gas initiative builds on the Year of Gas plan that was announced for 2020. A cornerstone of the initiative is the AjaokutaKaduna-Kano (AKK) pipeline. The 614-km pipeline is set to provide some 56mn m3/day of gas from new

assuage stakeholder concerns, the Edinburgh-based

fields to support up to 3.6 GW of power generation,

consultancy said. “Lower royalty and tax rates are

as well as gas-based industries along its route.

proposed. Marginal fields and indigenous producers

Construction began in July last year.

are expected to benefit more from favourable terms.”

The government meanwhile introduced the National Gas Expansion Programme last year, which aims to

A decade of gas

make compressed natural gas (CNG) the fuel of choice

PIB’s signing is the most important development in

for transportation, and liquefied petroleum gas (LPG) a

Nigeria’s oil and gas industry this year, and arguably

key fuel for domestic cooking, captive power facilities

in the past decade. But 2021 is also a noteworthy

and small industrial complexes. The programme is

year as it has seen the country unveil a major

backed by a 250bn naira ($650mn) intervention facility

initiative to establish Nigeria as a major producer and

created by the Central Bank of Nigeria.

consumer of natural gas. The government hopes that the improvements set out in PIB will help turn this vision into a reality. Indeed,

G L O B A L VO I C E O F G A S

The government is also promoting small-scale LNG supply and is seeking to eliminate gas flaring, to reduce emissions and unlock extra energy for use.

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Pakistan’s upstream declines will drive LNG demand Between declining domestic gas production and a lack of piped gas import options, the country’s LNG demand is set to continue growing ANDREW KEMP

G L O B A L VO I C E O F G A S

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he Pakistani government announced plans

The growing divide between supply and demand

for a new upstream bid round last month

forced the country to import its first cargo of LNG in

that it said would reduce the country’s

2015, with volumes growing from 1.5bn m3 that first

growing dependence on imports of currently

year to 11.8bn m3 in 2019, before they too eased to

expensive LNG.

10.6bn m3 in 2020.

The country has been caught up in a political

Pakistani Energy Minister Hammad Azhar warned

skirmish over expensive imports of the fuel and

on August 16 that the country’s natural gas reserves

the government is eager to mitigate some of the

were declining by around 10% each year. His

backlash. Unfortunately, between the country’s

comments came during a signing ceremony with Oil

limited domestic upstream potential and a distinct

and Gas Development Company Ltd (OGDCL) for five

lack of overland gas import options, Islamabad is

exploration licences.

unlikely to succeed on this front. The Pakistani Energy Ministry announced on July 30 that it intended to auction several attractive

He said the contract awards were an important step towards increasing upstream investment and eventually bridging the supply and demand gap.

blocks before the end of the year. However, the majority of the licences up for grabs were previously awarded and have either been cancelled or are still under litigation. “The government is … doubling down on its efforts to enhance gas production by launching the next exploration and production bidding round, targeting high-potential ‘surrendered’ and ‘under litigation’ blocks, by the year end,” the ministry. While the government is anxious to bolster flagging production and reserves, industry observers remain unconvinced about the country’s upstream potential and expect its LNG import dependency to continue growing. Indeed, as things stand, the country might be better served through an increase its portfolio of long-term LNG supplies in order to reduce its exposure to the spot market.

Swimming upstream Pakistani LNG consumption has grown steadily over the last seven years – barring last year when the pandemic slammed the brakes on economic activity. Natural gas production slid from 35.3bn m3 in 2011 to 32.7bn m3 in 2019 and 30.6bn m3 in 2020, according to BP’s Statistical Review of World Energy 2021. Consumption expanded from 35.3bn m3 in

Pakistani LNG consumption has grown steadily over the last seven years – barring last year when the pandemic slammed the brakes on economic activity.

2011 to 44.5bn m3 in 2019, before easing to 41.2bn m3 in 2020.

G L O B A L VO I C E O F G A S

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Pakistan has struggled for years with power shortages, caused in part by its overdependence on costly and polluting fuel oil. Lacking sufficient upstream prospects at home, the government has turned to LNG as a more affordable and cleaner solution. It launched its first LNG import terminal in 2015 and brought online a second in 2017. By 2019, its LNG intake had reached 11.8bn m3. Pakistan is eyeing a further expansion in the regasification capacity, although this will need to be accompanied by improvements to its internal gas and power infrastructure, as well as energy system management, to help it make chronic electricity shortages a thing of the past.

Given the lacklustre performance of the country’s oil and gas developers in recent years, coupled with an investment focus on expanding already producing

12.9mn mt/yr in 2025. Rystad Energy shares a similar outlook, with

fields rather than finding major new discoveries, the

analyst Kaushal Ramesh telling NGW that there

challenges on this front are many.

was only a “limited possibility” of substantial

“Exploration is focused in the onshore Indus basin but average commercial success rates have been low. In addition, the majority of spend is on producing

will grow from 6.93mn metric tons/year in 2020 to

new gas reserves being discovered in the near to medium term. Ramesh said: “We expect Pakistan’s LNG

assets with no major greenfield development on

imports to increase from around 7.5mn mt in 2021

the horizon. We expect gas production to decline

to 12mn mt by 2025 and potentially to 20mn mt by

resulting in import dependence growth,” Wood

2030. However, this would depend on the available

Mackenzie senior analyst Vidur Singhal told NGW.

regasification capacity and the price sensitivity of

The consultancy projects that Pakistan’s demand

Pakistani importers could mean imports during

G L O B A L VO I C E O F G A S

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periods of market tightness (2024-2026) could stay flat or even decline.” LNG prices have become a political hot potato in recent months, with opposition party Pakistan

The lack of piped gas options has therefore driven the country to begin building out a domestic gas grid that is underpinned by future LNG supplies.

Muslim League-Nawaz (PML-N) calling for a probe into state-owned Pakistan LNG Ltd’s (PLL) decision in

LNG in the pipeline

July to pay more than $15/mn Btu for spot deliveries

Pakistan signed a deal with Russia in May for

in September.

the construction of a 1,100-km pipeline that will pump gas from LNG import terminals in Karachi and

Pricing polemic

Gwadar to Lahore. The $2.5bn project should be

PML-N president Shehbaz Sharif described the price

completed by 2023 and will deliver up to

as “daylight robbery” in a July 31 tweet, adding:

12.3bn m3/yr to the country’s industrialised

“The [PTI] government failed to benefit from cheap

northern region.

RLNG rates during COVID-19 and is now making these costlier purchases. PTI’s incompetence and

dependency on natural gas across sectors, the

greed will [cost] our nation billions of dollars,”

government appears to have few viable alternatives

The government defended PLL’s decision by

[to LNG] for keeping the lights on, literally.”

arguing that not only does the country rely on the

Given soaring spot market costs, however,

spot market for around a third of its LNG supplies

Pakistan may find it more politically expedient to

but that a switch to fuel oil in the power sector

secure long-term supply contracts in the vein of its

would have proved far more costly.

10-year, 3mn mt/yr deal with Qatar that was signed

Pakistan’s import pricing problem is twofold, however. Not only is domestic gas production in decline but two high-profile transnational gas

in February. The Middle Eastern state is set to start exporting the fuel in 2022. Singhal said: “We anticipate more such long-

pipeline projects it has worked on for decades have

term deals as a means of lowering Pakistan’s

both repeatedly floundered.

import bill versus the alternative of LNG spot

Despite Iran and Pakistan first signing a deal in 1995 for the Iran-Pakistan-India (IPI) pipeline, with

market purchases in long run.” He added that current long-term LNG contracts

Pakistan completing its section in 2011, Islamabad

were being signed at around 10.2% Brent plus a

said in 2019 that as long as the US continued to

small constant, which represented a significant

impose sanctions on Tehran it could not proceed

discount to current spot prices. Singhal said: “Many

with the project.

sellers are currently offering bridging contracts

The Turkmenistan-Afghanistan-Pakistan-India (TAPI) pipeline’s future, meanwhile, has been thrown into doubt after the Taliban’s recent return to power

Singhal said: “Given Pakistan’s heavy

which combine lower short-term prices in exchange for longer term demand security.” Pakistan’s gas import dependency appears to

in Afghanistan after 20 years. Security challenges

be here to stay, despite the government’s hopes for

had already delayed the proposed pipeline and now

its next exploration bid round. Islamabad’s decision

it remains unclear how relations between the US,

to build a 1,100-km pipeline to feed LNG from the

its allies and the Taliban will unfold in the coming

southern coast to industrial centres in the north

weeks, months and years. Future sanctions are not

indicates the government is already preparing for

a remote possibility.

this likely future.

G L O B A L VO I C E O F G A S

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EU Fit for 55:

From an existential threat to an opportunity?

The European Commission unveiled on July 15 its Fit for 55 package, aimed at aligning current EU laws with 2030 and 2050 emissions targets. The publication was focused on the EU Emission Trading System revisions and the Carbon Border Adjustment Mechanism. By the end of the year the decarbonised gas package and the methane emissions strategy should be published to finalise the EU Green Deal vision.

G L O B A L VO I C E O F G A S

DR THIERRY BROS Professor, Sciences Po Paris

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he European Commission published its Fit

CO2 emissions from the power and manufacturing

for 55 package of legislative proposals

sectors from 2040.

on July 14, striving to align EU law with

There is another challenge for the long-term

the bloc’s new climate ambitions. Having read the

vision of the Commission: if CO2 emissions need

more than 800 pages focused on the EU Emissions

to go to zero by 2040, EU allowance (EUA) prices

Trading System (ETS) and the carbon border

will skyrocket to abate the last CO2 molecule (with

adjustment mechanism (CBAM), the first impression

inflationary risk not measured) before going to €0/

is the low quality of analysis1 and a written style

metric ton.

that makes it (purposely?) difficult2 to read.

There are ways to improve the way the system

Nevertheless, the publication is an existential threat

works however. For example, under the current

to the actual oil and gas business model. Perhaps

rules, the EU ETS does not recognise negative

the most striking conclusion is that, assuming the

emissions: indeed, the maximum amount of CO2

same new linear factor for ETS Phase 4 pre and

that can be credited is today limited to the amount

post 2030, the cap goes to 0 metric tons in 2040.

of CO2 that is emitted from installations covered by

In other words, there should therefore be no more

the EU ETS. The establishment of a market for

EU ETS cap 2013-2040e (excluding aviation & maritime) 2,000

(mtCO2e)

1,500

1,000

500

0 2013

2018

2023e

2028e

2033e

2038e

Source: European Commission, thierrybros.com

1 The analytical work completed for the ETS revision is low quality: important data are either missing (XX mt maritime sector is emitting today under this new regulation) or incorrect (117mn mt rebasing of ETS in 2024); the 2023-2030 hedging analysis doesn’t take into account: 1. maritime, 2. massive increase in industrial when free allowances will be reduced & 3. funds entering this new asset class (a carbon ETF is already available) to land magically at a 2030 hedging needs between 400 and 700mn mt, ie in the actual TNAC range (400-833mn mt). 2 On top of data & ref missing, same scenario being named differently in the report; outdate scenarios, extensive use of magic maths to allow massive private subsidy farming hoping that it can change the laws of physics.

G L O B A L VO I C E O F G A S

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carbon removal certificates3 which recognises

International arm twisting

negative emissions through both nature-based and

The CBAM is not a new idea. It was invented as an

technological solutions, and is compatible with the

“EU carbon tax” by French President Jacques Chirac

EU ETS, can therefore help balance the remaining

in 20074. It took 15 years to transform this idea into

effective emissions taking into account the merit

a “mechanism” as the European Commission would

order between competing abating technologies.

need an improbable unanimity inside the European

The outcome will be a net zero Europe where CO2

Council to implement a tax. This “mechanism” must

emitters will pay the EUA price for someone else

now be WTO compatible to avoid international issues

to take care of it by capture and sequestration. Let

and we already know that the US, Australia, Russia

us hope that this will be the outcome of a later EU

and China are opposing it.

ETS revision.

Oil and gas have not been included in the pilot 2023-2025 CBAM phase and the industry should

European political bargaining

avoid interfering on this highly political issue, leaving

The Commission is insisting that all those

it to Presidents Biden, Putin, von der Leyen and Xi.

legislative proposals are to be adopted if we want

The industry is facing a much more serious

to achieve the new targets of reducing greenhouse

threat about methane emissions (with the December

gas emissions by at least 55% by 2030. But, it also

publication) and should do whatever it takes to

needs the approval of both European Parliament

reduce those emissions to the bare minimum

and Member States. It is therefore highly uncertain

without spending hours in sterile discussions on the

that all proposals will go ahead. For example,

measurement methodology.

the European Commission has two reasons for creating a new separate ETS for buildings and

What options for the oil and gas industry?

road transport:

In front of an existential threat, the only viable option is to concentrate work, time and money on

• Phasing only maritime emissions to the actual ETS

what is likely the best option(s). Analysts can provide

from 2023 to 2026 would only add 5% allowances

in-depth views of the challenges ahead when the

and should be done without disrupting the actual

verified emissions might start to be above the cap,

system.

leading to extreme prices and political backlash. But

• However, building and road transport account for an additional 45% of emissions, and for that reason using a unified system for all emissions

as the investment time is at least a decade in energy, this is posing a threat to today’s oil and gas industry. The oil and gas industry is spending far too

could be greatly unpopular among the public –

much time in trying to engage with the European

due to the high energy cost implications of such a

Commission in a “damage control” approach. This

system.

has not been successful so far and is highly unlikely to ever be successful. The oil and gas industry should

Including building and road transport in an

leave some fights to others stakeholders that are

ETS system is going to be a barter between the

better positioned (MEPs for ETS building and road

Commission and the Parliament, and even the

transport, foreign states for CBAM) and fast adapt its

separate option might not be approved at the end.

business model to fit the EU 2030 targets.

3 European Commission Executive Vice President F. Timmermans in the 14/7/21 “Fit for 55” presentation 4 elysee-module-11141-fr.pdf

G L O B A L VO I C E O F G A S

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Hydrogen production costs Deducted

Auctioned

Free

Cap

Verified

2,300

1,800

1,300

800

300

-200

2030e

2029e

2028e

2027e

2026e

2025e

2024e

2023e

2022e

2021

2020

2019

2018

2017

2016

2015

2014

2013

-700

Source: European Commission, thierrybros.com

On top of reducing emissions (CO2 and CH4) to the bare minimum, one of the paths forward is to invest

to scale it up fast as we are running out of time. If it works it would provide a win-win-win solution:

massively in carbon capture & sequestration (CCS) to develop a circular economy where on one side oil

1. the oil and gas industry will keep its social licence

and gas will still be produced and used as cheap and

to provide fuels with no arm to the environment

reliable fuels to power our economy while on the other

as the CO2 emissions will be taken care of in

side, the CO2 emissions will be captured and stored in a permanent way. Technologies are either readily available (transportation, upstream knowledge) or need to be scaled up massively (capture & sequestration). What is

parallel; 2. the policymakers will have fostered a cleaner world with the least costly path; 3. the banking industry will be able to use the

making the problem more costly in Europe is the NIMBY

revised very liquid EU ETS to foster investment

factor that entails that CO2 storage needs to be far

in greener technologies and to provide real green

offshore to avoid upsetting voters. This looks difficult at

portfolios.

first sight, but this business model is exactly the one of water companies all over the world; they sell both clean water and the associated services of cleaning dirty water. This is an expensive solution and needs now massive capital expenditure and human resources

G L O B A L VO I C E O F G A S

Unfortunately, I do not see any real other alternatives. Even if the EU ETS is badly designed, the oil and gas industry needs to act now on CCUS to ensure that this existential crisis is averted.

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A Publication of the International Gas Union (IGU) in collaboration with Minoils Media Ltd. IGU Editorial Team Director, Public Affairs Paddy Blewer Sr. Manager, Public Affairs Tatiana Khanberg Sr. Advisor to the President Terence Thorn Sr. Advisor Public Affairs Marta Gonzalez

Global Voice of Gas BY T H E I N T E R N AT I O N A L GAS UNION ISSUE 05 | VOL 01

Sr. Advisor Public Affairs Hakon Huglen IGU Leadership President Joe M. Kang Vice President Li Yalan Vice President Andrea Stegher Past President David Carroll Secretary General Andy Calitz Advertising and Sponsorship Inquires advertise@naturalgasworld.com Publisher Minoils Media Ltd. Editor, Global Voice of Gas and Editor-in-chief, Natural Gas World Joseph Murphy Design Jeremy Seeman Senior Editors Dale Lunan Shardul Sharma

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G L O B A L VO I C E O F G A S

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Global Voice of Gas - Volume 1, Issue 5

Articles inside

Nigeria kickstarts decade of gas with new petroleum bill

Africa disproportionately hit by investors’ reluctance to back oil, gas

Pakistan’s upstream declines will drive LNG demand

Greening our gas grids: Should we leave for tomorrow what we can do today?

The decarbonisation prize of biomethane de-mystified

The US Gulf Coast is poised for rapid methane and CCS development

Gas in their sights: the fuel’s place in net-zero strategies

Methane pyrolysis: a potential gamechanger?

The road to net-zero: GECF’s perspective

Complementary colours: developing blue and green hydrogen trade

A sustainable flame: the role of gas in net zero

Clean technologies that will make gas and gas use emission-free

Making CCUS pay: The US perspective